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Home My WebLink About205-065New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/27/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-32 (PTD 205-065) MFC/LDL 06/25/2020 •Multi Finger caliper Report •Leak Detection Log ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 2050650 E-Set: 34132 Received by the AOGCC 10/27/2020 Abby Bell 10/27/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,894 feet N/A feet true vertical 4,360 feet N/A feet Effective Depth measured 8,894 feet 5,269 & 5,436 feet true vertical 4,360 feet 4,441 & 4,469 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 5,057' 4,388' 6.55" ZXP LTP Packers and SSSV (type, measured and true vertical depth)5.5"x7.625" ZXP LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 113' 2,746' 6,299' TVD 113' Oil-Bbl measured true vertical Packer 4" 8,894' 8,894' 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1840 29 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-065 50-029-23261-00-00 Plugs ADL0025518 / ADL0028231 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-315 230 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com 40 MILNE PT UNIT E-32 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 209 Gas-Mcf 190 Casing Pressure Tubing Pressure 14 Junk N/A Liner Liner Casing Conductor Size Surface Production N/A measured 3,635' 3,469' measured 2,661' 4,385' 4,441' 7,500psi Length 113' 2,711' 6,267' 5,210psi 6,892psi 8,430psi 777-8343 6,590psi 20" 10-3/4" 7-5/8" 4-1/2" 7,910psi 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,470psi 4,360' 4,790psi Burst N/A Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.08.18 12:49:37 -08'00' By Samantha Carlisle at 2:00 pm, Aug 18, 2020 RBDMS HEW 8/18/2020 DSR-8/18/2020 SFD 8/19/2020MGR30JUL2021 _____________________________________________________________________________________ Revised By: TDF 8-11-2020 SCHEMATIC Milne Point Unit Well: MPU E-32 Last Completed: 3/3/2019 PTD: 205-065 TD =8,894’(MD) / TD = 4,360’(TVD) 20” 7-5/8” x 10’ Marker Jt @ 5,332 to 5,342’’ 7-5/8” 12 13 & 14 10-3/4” 15 17 16 “OA” Lateral PBTD =8,894’(MD) / PBTD =4,360’(TVD) Tubing Patch Top @ 2,032’MD Btm @ 2,098’MD “NC/ND” Lateral 1 2 4 3 5 & 6 7 8 & 9 10 Orig. KB Elev.: 57.70’/ Orig. RT-LDS : 30.30’ Doyon 14 18 & 19 20 21 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 113' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 2,746’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,299’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT-M 3.958 5,259’ 8,894’ 4” Liner “NC/ND” 9.5 / L-80 / IBT-M 3.548 5,425’ 8,894’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / IBT-M 2.441 Surface 5,057’ SLOTTED LINER DETAIL 4-1/2” OA 12.6 / L-80 / IBT 3.958 5,332’ 8,851’ 4 NC/ND 12.6 / L-80 / IBT 3.548 6,303’ 8,849’ JEWELRY DETAIL No Depth Item 1169’ST 2: 2-7/8" GLM w/ 1" DPSOV BK Latch 24,810’ST 1: 2-7/8” x 1” TMPD GLM w/ DV, SBK-2C Latch 3 4,928’ 2-7/8” XN Profile -2.205” No-Go 4 4,979.9’ Discharge Head: FPDIS 5 4,980’ Pump: SXD 134FLEX ER 6 5,004’ Pump: SXD 134FLEX ER 7 5,028’ Gas Separator: GSV XM FER NO 8 5,031’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 5,038’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,045’ Motor: 562 XP - 100Hp/ 1,820V/ 34A 11 5,053’ Sensor: Phoenix XT150 12 5,055’ Centralizer: Bottom @ 5,057’ 13 5,259’ Liner Tie Back Sleeve 14 5,269’ Baker ZXP Liner Top Packer 15 5,295’ 4-1/2” Hook Hanger ‘LEM’ Above Hanger 16 5,305’ 4-1/2” Hook Hanger ‘LEM’ Inside Hanger 17 5,322’ Hook Wall Hanger Outside 18 5,425’ Baker Liner Tie Back Sleeve 19 5,436’ Baker ZXP Liner Top Packer 20 5,443’ Baker HMC Liner Hanger 21 5,459’ 4.5” Non Locating Seal Assy. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260sx of Arctic Set (Approx.) in 42” Hole 10-3/4" Cmt w/ 345sx AS Lite, 371sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 725sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 450’ MD +60 Degrees from 750’ Tbg Max Angle= 69.0 deg @ 4,750’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” x 7-1/16” 5M FM Gen 5A, w/ 2- 7/8” FMC Tbg Hgr, 3” LH Acme on top and 2-7/8” EU 8rd on btm. 2.5” CIW BPV Profile. GENERAL WELL INFO API: 50-029-23261-00-00 & 50-029-23261-60-00 Drilled and Cased by Doyon 14 – 5/26/2005 ASR #1 RWO – 3/4/2019 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,310’ MD/ Bottom @ 5,322’ MD/ Angle @ top of window is 79 deg Well Name Rig API Number Well Permit Number Start Date End Date MP E-32 Slick Line 50-029-23261-00-00 205-065 8/6/2020 8/7/2020 No operations to report. No operations to report. 8/8/2020 - Saturday No operations to report. 8/11/2020 - Tuesday 8/9/2020 - Sunday No operations to report. 8/10/2020 - Monday 8/7/2020 - Friday Pressure test TBG. (pressure test equipment 274/2,237psi) Pumped 8.4 bbls diesel down TBG to reach 1,500psi for test. Bleed back 1.5 bbls. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/ 2,500H. SET G-PACKOFF PATCH FROM 2,084' SLM/ 2,098' MD TO 2,018' SLM/ 2,032' MD. SET D&D HOLEFINDER ON TOP OF PATCH AT 2,018' SLM/2,032' MD. LRS TEST TBG TO 1,500psi (good, see LRS log) PULL D&D HOLEFINDER OUT OF HOLE. RDMO, CLOSE PERMIT W/PAD-OP. 8/5/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/6/2020 - Thursday Assist Slickline set patch. (Pressure test equipment 274/2,501 psi) Pump 20 bbls Diesel down TBG while HSL ran Horse tail. Pumped 30 bbls 120°F Diesel down TBG while HSL for Brush n flush. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/ 2,500H. RUN 1.75" SAMPLE BAILER WITH FRAYED ROPE STRANDS AND FIND LEAK AT 2,041' SLM/2,055' MD (14' correction). BRUSH TBG FROM 1,900' SLM TO 2,200' SLM WITH LRS PUMPING 30bbls 120 DEG DIESEL. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,894'N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi Liner 7,500psi Liner 6,590psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6.55" ZXP LTP & 5.5" x 7.625" ZXP LTP and N/A 5,269 MD / 4,441 TVD & 5,436 MD / 4,469 TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8,894' See Schematic 4" Perforation Depth TVD (ft): 3800 Centerpoint Dr, Suite 1400 MILNE PT UNIT E-32 C.O. 477.05 8,894'4-1/2"3,635' 6,267' 3,469' 4,360' Authorized Signature: 8/5/2020 2-7/8" Perforation Depth MD (ft): See Schematic 2,746' 6,299' 113' 20" 10-3/4" 7-5/8" 2,711' N/A 8,430psi 5,210psi 6,892psi 2,661' 4,385' 4,441' N/A MILNE POINT / SCHRADER BLUFF OIL 113' 113' 6.5# / L-80 / IBT-M TVD Burst 5,057' 7,910psi MDLength Size 4,360' 8,894' 4,360' 861 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 / ADL0028231 205-065 Anchorage Alaska 99503 50-029-23261-00-00 Hilcorp Alaska LLC Tubing Grade:Tubing MD (ft): David Haakinson COMMISSION USE ONLY Authorized Name: Tubing Size: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 7:20 am, Jul 30, 2020 320-315 Chad A Helgeson 2020.07.29 15:44:01 -08'00' 10-404 X DLB 07/30/20 DSR-7/30/2020MGR05AUG20Comm 8/4/2020 dts 78/4/2020 JLC 8/4/2020 RBDMS HEW 8/5/2020 Tubing Patch Well: MPU E-32 Date: 07-28-2020 Well Name:MPU E-32 API Number: 50-029-23261-00-00 Current Status:Shut In- ESP Producer Pad:E-Pad Estimated Start Date:August 5th, 2020 Wellwork unit:SL/EL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:205-065 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 AFE Number:Job Type:Tubing Patch Current Bottom Hole Pressure: 1,203 psi @ 4,386’ TVD ESP Gauge (7/28/2020) |5.3 PPG Maximum Expected BHP:1,300 psi @ 4,386’ TVD Stable SBHP |5.7 PPG MPSP:861 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 19° @ patch set depth MIN ID:2.441” to patch set depth Brief Well Summary: MPU E-32 was drilled and completed as a dual lateral OA and N-Sand producer in 2005. A RWO was completed in Q1 2019 with new tubing installation. In July 2020, the well developed a tubing leak at 2,054’ MD and the well stopped surfacing fluids. The well was producing 200 BOPD prior to failure. Notes Regarding Wellbore Condition x Well was SI on 7/22/2020 due to increasing FBHP and increase in downhole motor load. x Single Tubing leak confirmed at 2,054’ MD on 7/25/2020 with E-line leak detect. o Joint 66 (identified with the leak) and Joint 67 are noticeably more damaged (pitted) than the other joints. Objective: x Set D&D tubing patch (Sundry Approval Required) x Backup Contingency: o E-line Paragon packer patch Procedure Slickline 1. MIRU SL. PT lubricator to 200 psig low, 2,500 psig high. 2. RU LRS for pump support 3. RIH w/ rope leak detect to leak interval and locate leak depth at 2,054’ MD. a. CorrelateD to SL Memory Spinner/GR/CCL log dated 7-25-2020. 4. Flag wire and POOH. 5. Brush and Flush tubing at patch setting interval (±50’ up/down from leak point). 6. RIH with tubing slip-stop and set 42’ below leak depth (flagged wire) @ ±2,096’ MD. 7. Set D&D pack-off on slip-stop. 8. RIH with stinger, spacer pipe, and receptacles to make tubing patch at ±52’ element to element. 9. Land in lower D&D pack-off seal assembly and set upper D&D pack-off. Tubing Patch Well: MPU E-32 Date: 07-28-2020 10. Set upper D&D pack-off at a target depth of ±2,044’ MD. 11. RIH with D&D test tool and land in upper packer. 12. PT tubing to 1,500 psig to confirm upper packer and up-hole tubing integrity. 13. After passing test, RIH w/ 2.875” tubing stop and set on top of upper D&D pack-off. 14. RDMO Slick-line and LRS. Leave well SI. Contingency Tubing Patch Set (If D&D patch is unsuccessful) E-line 1. MIRU EL. PT lubricator to 200 psig low, 2,500 psig high. 2. RIH with GR/CCL and 2.875” paragon packer and set packer mid-element @ ±2,096’ MD a. Correlate to SL Memory Spinner/GR/CCL log dated 7-25-2020. Slickline 3. MIRU SL. PT lubricator to 200 psig low, 2,500 psig high. 4. RIH with latch seal assembly, +/- 52’ of 1.9” spacer pipe in two intervals, and top 2.875” paragon packer. 5. Land in lower paragon packer and set top packer mid-element @ ±2,044’ MD 6. RIH with 2.875” paragon packer test tool and land in upper packer. 7. PT tubing to 1,500 psig to confirm upper packer and up-hole tubing integrity. 8. RDMO Slick-line Attachments: 1) Current Schematic 2) Proposed Schematic _____________________________________________________________________________________ Revised By: TDF 3/5/2019 SCHEMATIC Milne Point Unit Well: MPU E-32 Last Completed: 3/3/2019 PTD: 205-065 TD =8,894’(MD) / TD = 4,360’(TVD) 20” 7-5/8” x 10’ Marker Jt @ 5,332 to 5,342’’ 7-5/8” 12 13 & 14 10-3/4” 15 17 16 “OA” Lateral PBTD =8,894’(MD) / PBTD =4,360’(TVD) “NC/ND” Lateral 1 2 4 3 5 & 6 7 8&9 10 Orig. KB Elev.: 57.70’/ Orig. RT-LDS : 30.30’ Doyon 14 18 & 19 20 21 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 113' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 2,746’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,299’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT-M 3.958 5,259’ 8,894’ 4” Liner “NC/ND” 9.5 / L-80 / IBT-M 3.548 5,425’ 8,894’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / IBT-M 2.441 Surface 5,057’ SLOTTED LINER DETAIL 4-1/2” OA 12.6 / L-80 / IBT 3.958 5,332’ 8,851’ 4 NC/ND 12.6 / L-80 / IBT 3.548 6,303’ 8,849’ JEWELRY DETAIL No Depth Item 1169’ST 2: 2-7/8" GLM w/ 1" DPSOV BK Latch 24,810’ST 1: 2-7/8” x 1” TMPD GLM w/ DV, SBK-2C Latch 3 4,928’ 2-7/8” XN Profile -2.205” No-Go 4 4,979.9’ Discharge Head: FPDIS 5 4,980’ Pump: SXD 134FLEX ER 6 5,004’ Pump: SXD 134FLEX ER 7 5,028’ Gas Separator: GSV XM FER NO 8 5,031’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 5,038’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,045’ Motor: 562 XP - 100Hp/ 1,820V/ 34A 11 5,053’ Sensor: Phoenix XT150 12 5,055’ Centralizer: Bottom @ 5,057’ 13 5,259’ Liner Tie Back Sleeve 14 5,269’ Baker ZXP Liner Top Packer 15 5,295’ 4-1/2” Hook Hanger ‘LEM’ Above Hanger 16 5,305’ 4-1/2” Hook Hanger ‘LEM’ Inside Hanger 17 5,322’ Hook Wall Hanger Outside 18 5,425’ Baker Liner Tie Back Sleeve 19 5,436’ Baker ZXP Liner Top Packer 20 5,443’ Baker HMC Liner Hanger 21 5,459’ 4.5” Non Locating Seal Assy. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260sx of Arctic Set (Approx.) in 42” Hole 10-3/4" Cmt w/ 345sx AS Lite, 371sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 725sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 450’ MD +60 Degrees from 750’ Tbg Max Angle= 69.0 deg @ 4,750’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” x 7-1/16” 5M FM Gen 5A, w/ 2- 7/8” FMC Tbg Hgr, 3” LH Acme on top and 2-7/8” EU 8rd on btm. 2.5” CIW BPV Profile. GENERAL WELL INFO API: 50-029-23261-00-00 & 50-029-23261-60-00 Drilled and Cased by Doyon 14 – 5/26/2005 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,310’ MD/ Bottom @ 5,322’ MD/ Angle @ top of window is 79 deg _____________________________________________________________________________________ Revised By: DAH 07-28-2020 PROPOSED Milne Point Unit Well: MPU E-32 Last Completed: 3/3/2019 PTD: 205-065 TD =8,894’(MD) / TD = 4,360’(TVD) 20” 7-5/8” x 10’ Marker Jt @ 5,332 to 5,342’’ 7-5/8” 12 13 & 14 10-3/4” 15 17 16 “OA” Lateral PBTD =8,894’(MD) / PBTD =4,360’(TVD) “NC/ND” Lateral 1 2 4 3 5 & 6 7 8&9 10 Orig. KB Elev.: 57.70’/ Orig. RT-LDS : 30.30’ Doyon 14 18 & 19 20 21 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 113' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 2,746’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,299’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT-M 3.958 5,259’ 8,894’ 4” Liner “NC/ND” 9.5 / L-80 / IBT-M 3.548 5,425’ 8,894’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / IBT-M 2.441 Surface 5,057’ SLOTTED LINER DETAIL 4-1/2” OA 12.6 / L-80 / IBT 3.958 5,332’ 8,851’ 4 NC/ND 12.6 / L-80 / IBT 3.548 6,303’ 8,849’ JEWELRY DETAIL No Depth Item 1169’ST 2: 2-7/8" GLM w/ 1" DPSOV BK Latch 24,810’ST 1: 2-7/8” x 1” TMPD GLM w/ DV, SBK-2C Latch 3 4,928’ 2-7/8” XN Profile -2.205” No-Go 4 4,979.9’ Discharge Head: FPDIS 5 4,980’ Pump: SXD 134FLEX ER 6 5,004’ Pump: SXD 134FLEX ER 7 5,028’ Gas Separator: GSV XM FER NO 8 5,031’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 5,038’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,045’ Motor: 562 XP - 100Hp/ 1,820V/ 34A 11 5,053’ Sensor: Phoenix XT150 12 5,055’ Centralizer: Bottom @ 5,057’ 13 5,259’ Liner Tie Back Sleeve 14 5,269’ Baker ZXP Liner Top Packer 15 5,295’ 4-1/2” Hook Hanger ‘LEM’ Above Hanger 16 5,305’ 4-1/2” Hook Hanger ‘LEM’ Inside Hanger 17 5,322’ Hook Wall Hanger Outside 18 5,425’ Baker Liner Tie Back Sleeve 19 5,436’ Baker ZXP Liner Top Packer 20 5,443’ Baker HMC Liner Hanger 21 5,459’ 4.5” Non Locating Seal Assy. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260sx of Arctic Set (Approx.) in 42” Hole 10-3/4" Cmt w/ 345sx AS Lite, 371sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 725sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 450’ MD +60 Degrees from 750’ Tbg Max Angle= 69.0 deg @ 4,750’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” x 7-1/16” 5M FM Gen 5A, w/ 2- 7/8” FMC Tbg Hgr, 3” LH Acme on top and 2-7/8” EU 8rd on btm. 2.5” CIW BPV Profile. GENERAL WELL INFO API: 50-029-23261-00-00 & 50-029-23261-60-00 Drilled and Cased by Doyon 14 – 5/26/2005 ASR #1 RWO – 3/4/2019 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,310’ MD/ Bottom @ 5,322’ MD/ Angle @ top of window is 79 deg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing ✓ Operations shutdownLl Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Apph0 ad Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: ESP Change -out ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 205-065 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23261-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025518 / ADL0028231 MILNE PT UNIT E-32 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 8,894 feet Plugs measured N/A feet true vertical 4,360 feet Junk measured N/A feet Effective Depth measured 8,894 feet Packer measured 5,269 & 5,436 feet true vertical 4,360 feet true vertical 4,441 & 4,469 feet Casing Length Size MD TVD Burst Collapse Conductor 113' 20" 113' 113' N/A N/A Surface 2,711' 10-3/4" 2,746' 2,661' 5,210psi 2,470psi Production 6,267' 7-5/8" 6,299' 4,385' 6,892psi 4,790psi Liner 3,635' 4-1/2" 8,894' 4,441' 8,430psi 7,500psi Liner 3,469' 4" 8,894' 4,360' 7,910psi 6,590psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 / EUE 8rd 5,057' 4,388' 6.55" ZXP LTP Packers and SSSV (type, measured and true vertical depth) 5.5"x7.625" ZXP LTP N/A See Above WA 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 168 11 65 220 224 Subsequent to operation: 22 2 22 260 33 14. Attachments (required Per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations B Exploratory Development F±1 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 21 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-050 Authorized Name: Chad Helgeson / Contact Name: Taylor Wellman 71 Authorized Title: Operations Manager Contact Email: twellman(a7hilcorp.com Authorized Signature: Date: 3/5/2019 Contact Phone: 777-8449 ��f 1� 3 RBDMS. MAR 0 7 2019 Form 10-404 Revised 4/2017`s 'f/2ryt2/ Submit Original Only Orifi KB Bev: 57.70`/ Orig. RT -LDS: 30.301 10-3/4" 586 e&9 13 & 14 '04 -Lab. -al 21 16&19 "NOW LskrA SCHEMATIC 11" x 7-1/16" 5M FM Gen 5A, w/ 2 Wellhead 7/8 FMC Tbg Hgr, 3" LH Acme on top and 2-7/8" EU 8rd on btm. 2.5" Milne Point Unit Well: MPU E-32 Last Completed: 3/3/2019 PTD: 205-065 OPEN HOLE/ CEMENT DETAIL nt w/ 260sx of Arctic Set (AVDrox.) in 42" Hole 1 7-5/8" 1 Cmt w/ 725sx Class "G" in 9-7/8" Hole I CASING DETAIL Size I Type Wt/Grade/Conn ID I Top Btm 20" Conductor 92/H-40/Welded N/A Surface 113' 10-3/4" Surface 45.5 / L-80 / BTC i 9.950 Surface 2,746' 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.875 Surface 6,299' 4-1/2" Liner "OA" 12.6/ L-80 / IBT-M 3.958 5,259' 8,894' 4" Liner "NC/ND" 9.5 / L-80 / IBT-M 3.548 5,425' 8,894' TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / IBT-M 1 2.441 Surface 5,057' SLOTTED LINER DETAIL 4-1/2" OA 12.6 / L-80 / IBT 3.958 5,332' 8,851' 4 NC/ND 12.6/L-80/IBT 3.548 6,303' 8,849' WELL INCLINATION DETAIL KOP @ 450' MD +60 Degrees from 750' Tbg Max Angle= 69.0 deg @ 4,750' MD LATERAL WINDOW DETAIL Top of "OA" Window @ 5,310' MD/ Bottom @ 5,322' MD/ Angle @ top of window is 79 deg JEWELRY DETAIL No Depth Item 1 169' ST 2: 2-7/8" GLM w/ 1" DPSOV BK Latch 2 4,810' ST 1: 2-7/8" x 1" TMPD GLM w/ DV, SBK-2C Latch 3 4,928' 2-7/8"XN Profile - 2.205" No -Go 4 4,979.9' Discharge Head: FPDIS 5 4,980' Pump: SXD 134FLEX ER 6 5,004' Pump: SXD 134FLEX ER 7 5,028' Gas Separator: GSV XM FER NO 8 5,031' Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 5,038' Lower Tandem Seal: GSB3DBUTSB/SB PFSA 10 S,045' Motor: 562 XP - 100Hp/ 1,820W 34A 11 5,053' Sensor: Phoenix XT150 12 5,055' Centralizer: Bottom @ 5,057' 13 5,259' Liner Tie Back Sleeve 14 5,269' Baker ZXP Liner Top Packer 15 5,295' 4-1/2" Hook Hanger'LEM'Above Hanger 36 5,305' 4-1/2" Hook Hanger'LEM' Inside Hanger 17 5,322' Hook Wall Hanger Outside 18 5,425' Baker Liner Te Back Sleeve 19 5,436' Baker UP Liner Top Packer 20 5,443' 1 Baker HMC Liner Hanger 21 5,459' 1 4.5" Non Locating Seal Assy. GENERAL WELL INFO API: 50-029-23261-00-00 & 50-029-23261-60-00 Drilled and Cased by Doyon 14-5/26/2005 TD=8,894' (ND)/TD=4,360'(TM) PBTD-8'894 (ND)/P91D=4,360'(M) Revised By: TDF 3/5/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit NumberStart Date End Date MP E-32 ASR#1 50-029-23261-00-00 205-065 1 2/27/2019 3/3/2019 Daily Operations. 2/27/2019- Wednesday Standby for I -Rig to finish operations. Move rig and equipment from A -Pad to E-32 MIRU, Prep for BOPE Test as per sundry 250low/2,500high/5 min BOPE/Annular. 2/28/2019 -Thursday Continue MIRU and prep for BOP Test, electricians connect and test Fire and Gas system. Test BOPE as per sundry. 250low/2500high/5min BOPE/Annular 2-7/8"-3-1/2" VBR's. Check IA Pressure @ 0 psi. Remove the test sub, Attempt to pull BPV But there was some pressure under BPV. Pumped 20 bbls dwn tbg and pulled BPV. Had issue with Rig WT indicator. Trouble shoot the problem. POOH with 2-7/8" 6.5# EUE/ with ESP 155 jnts , 3 GLM's ( Conduct well control drill on the floor with pump at surface). 3/1/2019 - Friday Continue and complete laying down ESP assembly. S/I well and perform fluid checks on equipment. Swap out handling equipment and tubulars. Prep to run 7-5/8" casing scraper on 3.5" Work String. Start RIH w/ 7-5/8" Casing Scraper with 10.3# 3.5" ASR Work -string. RIH to 5,160' MD reciprocating pipe with scraper. Prep to POOH. POOH with 10.3 # 3.5" ASR Work -string w/ 7-5/8" casing scraper laying down. Pick up and Make up 7-5/8" Arrow set CSG test PKR,3.5" EUE pin x 3.5"RTS8 box, 3.5" RTS8 pin x 2-7/8" IF box. RIH with 3.5" 10.37# DP to 5150'. Set Arrowset PKR, Fill CSG 46bbl=1345'MD, test CSG to 1 500 si 30min chart. test good n/l (( S I tI 3/2/2019 -Saturday Weatherford Arrowset packer @ 5,150 feet with hole full of 8.4ppg source water. Pressure test 7-5/8" casing to 1,500psi for 30 minutes for good test. Bleed off pressure and prep to pull packer. Attempt pull packer as per Weatherford procedure. Put 1.5 turn torque to right and P/U to 52K. Tubing indicating packer equalizing thru internal equalization port. Wait 15 mins, P/U to 55K without packer release. Set down to 33 K and put 1.5 more turn into tubing (total 3 turns) P/U to 70 K and packer pulled free and all torque lost. Let elements rest 10 mins and start POOH. S/D pulling 3.5" 10.4# work -string and 7- 5/8" test packer and perform all fluid checks. Continue POOH w/ 3.5" 10.4# ASR work -string and 7-5/8" test packer. Pumping double displacement with 8.4# source water. Swap out lifting gear, tubulars, and prep to P/U ESP. P/U ESP assembly WITHOUT capillary string and RIH on 2-7/8" L-80 6.5# EUE tubing clamping as per Centrilift schedule. Pumping double displacement with 8.4 ppg Source Water while RIH. Cont. RIH on 2-7/8" L-80 6.5# EUE tubing clamping as per Centrilift schedule. Testing cable every 1000', Pumping double displacement with 8.4 ppg Source Water while RIH. Make up landing TBG hanger, make ESP cable splice. Land tbg EOT @ 5,054', XN @ 4927', Lower GLM/w Dummy @ 4,809', Upper GLM/W DPSOV @ 168' Total clamps - 4 Seal Clamps, 8 -Pump clamps and 80 X -collar clamps. 3/3/2019 -Sunday Continue completing wellhead termination work, install BPV and prep to start de -mob to E-35. Start Rig maintenance, Install Top drive on the rig tool carrier, conduct EAM's. RDMO, NO BOPE, NU 2-1/16" 5,000# Production well head. Test void 500 si/low 5,000 si hi h. Pull BPV. RDMO and stand ready to move to E-35. 3/4/2019 - Monday No activity to report. 3/5/2019 -Tuesday No activity to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-32 Permit to Drill Number: 205-065 Sundry Number: 319-050 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaskc.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, z � Daniel T. Seamount, Jr. Commissioner DATED this Sday of February, 2019. SCANNED FEB 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 91) AAc 95 9A0 R',o !E C EE �V E E FEB 0 1 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q . Stratigraphic ❑ Service ❑ 205-065 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23261-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT E-32 9. Property Designation (Lease Number): 10. Field/Pool(s): • ADL0025518 / ADL0028231 I MILNE POINT/ SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,894' 4,360' 8,894' 4,360' 320 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 113' 20" 113' 113' N/A N/A Surface 2,711' 10-3/4" 2,746' 2,661' 5,210psi 2,470psi Production 6,267' 7-5/8" 6,299 4,385' 6,892psi 4,790psi Liner 3,635' 4-1/2" 8,894' 4,441' 8,430psi 7,500psi Liner 3,469' 4" 8,894' 4,360' 7,910psi 6,590psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size. Tubing Grade: Tubing MD (ft): See Schematic See Schematic 6.5#! L-80 / IBT-M 5,064 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 6.55" ZXP LTP & 5.5"x 7.625" ZXP LTP and N/A 5,269 MD / 4,441 TVD & 5,436 MD / 4,469 TVD and N/A 12. Attachments: Proposal Summary K Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ® Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/2812018 OIL WINJ ❑WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellmaD hilcor .GOBI Contact Phone: 777-8449 Authorized Signature: ei Date: 2/1/2019 If COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L//� L✓, Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: r' A, -7� / G cis , � %.� 5 f" L 57O 6 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / U — 4y Q y f APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date. f / 2.5 Fonn 10-403 Revised 4/2017 Approved RBDMS ed app0y ti rRs1]GfJr N fr r from to al. 0 5 2019 Submit Form and Attachments in Duplicate U Nil.m Alaska. Lb ESP Change -Out Well: MPU E-32 Date:01/30/2019 Well Name: MPU E-32 API Number: 50-029-23261-00 Current Status: Shut in — ESP Down Pad: E -P d Estimated Start Date: February 28, 2019 Rig: Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 205-065 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,333 psi @ 4,331' TVDss BHP after 5 day SI —July 2018 / 5.92 ppg EMW Maximum Expected BHP: 1,333 psi @ 4,331' TVDss BHP after 5 day SI —July 2018 / 5.92 ppg EMW MPSP: 320 psi (Maximum IA Pressure recorded on 12/19/16) Brief Well Summary: MPU E-32 was drilled and completed as a multilateral producer in the OA and NC/ND Schrader Bluff Sands. The well was completed with an ESP completion in May 2005. The ESP had an amazing run life of 14 years and this will be the first ESP changeout in its history. Notes Regarding Wellbore Condition • The 7-5/8" casing passed an MIT -IA to 1,500psi on 5/24/2005 (during the original completion). Obiective: Pull the failed ESP and run a new ESP completion. Pre -Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. K_vJ� 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.5 ppg sea water prior to pulling BPV. Set TWC. Test BOPE to 250 psi Low/ 2 Sl 00 psi High, annular to 250 psi Low/ 2,500 psi High (hold each Y ! ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. e U Hilmrp Alaska, LL, ESP Change -Out Well: MPU E-32 Date:01/30/2019 a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" & 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2014 ESP running was 82K lbs / SOF = 76K lbs (Block weight= 50K lbs). v b. If needed, circulate (long or reverse) pill with lubricant and/or baraclean pill prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Take all tubing to G&I for washing and disposal. Lay down ESP. a. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over -torqued connections from previous tubing runs. c. The completion has the following amount of clamps/guards: i. 5 Protectors ii. 3 Flat Gaurds iii. 87 LaSalle Clamps: lea Jnts 1-9; lea every other Jnt; lea on GLM pups 18. MU 7-5/8" scraper BHA and TIH w/ 3-1/2" workstring to ±5,100' md. Reciprocate and circulate wellbore clean. 1<19. POOH and LD scraper BHA. /f 20. MU 7-5/8" test packer and TIH on 3-1/2" workstring to ±5,100' md. P�� H fllleoq, Alaska, LU ESP Change -Out Well: MPU E-32 Date:01/30/2019 21. Set test packer and pressure test 7-5/8" casing to 1,500psi for 30 min (charted). 22. Unseat test packer, POOH and LD test packer. 23. PU new ESP with single cap string and RIH on 2-7/8" tubing. Set base of ESP assembly at ± 5,055' MD. a. Upper GLM @ ± 140' MD w/SO b. 2-7/8" tubing c. Lower GLM w/ DGLV d. 3 joints of 2-7/8" tubing e. 2-7/8" XN (2.205" No -Go) f. 1 joint of 2-7/8" tubing g. Downhole gauge for discharge temperature and pressure (connected with a jumper from the lower sensor. Does not require a separate tech wire). h. Base of ESP centralizer @ ±5,055' MD 24. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 25. Set BPV. Post -Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPS. 28. NU existing 2-9/16" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form Moir Milne Point Unit MOM Well: MPU E-32 SCHEMATIC Last Completed: 5/26/2005 Hit, oi, Alaska, LLC PTD: 205-065 r TREE & WELLHEAD OPEN HOLE/ CEMENT DETAIL Tree 2-9/16- SM FMC 20" Cmtw/260sz of Arctic Set(Approx.) in 42" Hole 11"x7 -1/16"5M FM Gen 5A, w/ 2- 10-3/4" Cmt w/ 345sz AS Lite, 371sx Class "G" in 13-1/2" Hole Orig. KB Elev.: 57.70'/Orifi RT-LDS:30.39 7/8" FMC Tbg Hgr, 3" LH Acme on 7-5/8" Cmt w/ 725sx Class "G" in 9-7/8" Hole DDVon 14 Wellhead top and 2-7/8" EU 8rd on btm. 2.5" s x CIW BPV Profile. I U .� a CASING DETAIL 103/4" 7-W.10, Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40/ Welded N/A Surface 113' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,746 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.875 Surface 6,299' 4-1/2" Liner "OA" 12.6/ L-80 / IBT-M 3.958 5,259' 8,894' 4" Liner "NC/ND" 9.5 / L-80 / IBT-M 3.548 5,425' 8,894' TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / IBT-M 1 2.441 Surface 5,916' SLOTTED LINER DETAIL 4-1/2" OA 12.6/L-80/IBT 3.958 5,332' 8,851' 4 NC/ND 12.6/L-80/IBT 3.548 6,303' 8,849' WELL INCLINATION DETAIL KOP @ 450' MD +60 Degrees from 750' Tbg Max Angle= 69.0 deg @ 4,750' MD LATERAL WINDOW DETAIL Top of "OA" Window @ 5,310' MD/ Bottom @ 5,322' MD/ Angle @ top of window is 79 deg 6&7 9&10 "DA'Leleml 21 7 73 18 &19 20 "W D"Lasm JEWELRY DETAIL No Depth Item 1 148' ST 3: 2-7/8" x 1" TMPD GLM w/ Dual Orifice & BEK Latch 2 2,018' ST 2: 2-7/8" x 1" TMPD GLM w/ Dual Orifice & BEK Latch 3 4,819' ST 1:2-7/8" x 1" TMPD GLM w/ DV, SBK-2C Latch 4 4,971' 2-7/8" XN Profile -2.205" No -Go 5 4,992.7' Discharge Head-GPDIS 6 4,993' Pump-GPMTARI:1 7 5,014' Pump-GPMTAR3:1 8 5,021' Gas Separator-GRSFTXAR H6 9 5,025' Upper Tandem Seal-GSB3DBUTAB/HSN PFSA 10 5,032' Lower Tandem Seal -GSB3DBLTAB/HSN FSA CL5 11 5,039' Motor-KMH: 250Hp/2,305V/60A 12 5,059' Pump Mate Sensor & Centralizer - Bottom @5,064' 13 5,259' Liner Tie Back Sleeve 14 5,269' Baker ZXP Liner Top Packer IS 5,295' 4-1/2" Hook Hanger'LEM' Above Hanger 16 5,305' 4-1/2" Hook Hanger'LEM' Inside Hanger 17 5,322' Hook Wall Hanger Outside M5,425' Baker Liner Tie Back Sleeve 19 5,436' Baker ZXP Liner Top Packer 20 5,443' BakerHMC Liner Hanger 21 5,459' 4.5" Non Locating Seal Assy. GENERAL WELL INFO -00 50-029-23201-60-00 DAPriIlle5d0d9C2a3s2e0 dbyoyo&n 4-5262605 TD=8,894' (ND)/TD=4,3W0W) PBTD=8,894' (NU) / PBTD=4,36OF(TV)) Revised By: TDF 1/30/2019 H Hil,n,P Alaska. LLC Dlig. KB Bev.: 57.70'/ Orig, RT -LDS: 30.34 10 3/4" 4 1 1 5&6 7-W x 10 14 5,332to5,342' 7-5/8" 16 77818 79 `WA -u l-akral TD=8,894' (M0)/TD=4,3W(TVD) PBTD=8,894' (M0) / PBTD=4,360'(M) PROPOSED SCHEMATIC 11"x7 -1/16"5M FM Gen 5A, w/ D Wellhead 7/8 FMC Tbg Hgr, 3" LH Acme on top and 2-7/8" EU and on btm. 2.5" Milne Point Unit Well: MPU E-32 Last Completed: 5/26/2005 PTD: 205-065 OPEN HOLE/ CEMENT DETAIL nt w/ 260sx of Arctic Set (Approx.) in 42" Hole 1 7-5/8" 1 Cmt w/ 725sx Class "G" in 9-7/8" Hole I CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 113' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,746' 7-5/8" Intermediate 29.7 / L-80 / BTC -MOD 6.875 Surface 6,299' 4-1/2" Liner"OA" 12.6/L-80/IBT-M 3.958 5,259' 8,894' 4" Liner "NC/ND" 9.5 / L-80 / IBT-M 3.548 5,425' 8,894' TUBING DETAIL 2-7/8" Tubing 6.5 /L-80 /IBT-M 1 2.441 Surface 5,916' SLOTTED LINER DETAIL 4-1/2" OA 12.6IL -80 /IBT 3.958 5,332' 8,851' 4 NC/ND 12.6/ L-80 /IBT 3.548 6,303' 8,849' WELL INCLINATIONDETAIL KoP @ 450' MD +60 Degrees from 750' Tbg Max Angle= 69.0 deg @ 4,750' MD LATERAL WINDOW DETAIL Top of "OA" Window @ 5,310' MD/ Bottom @ 5,322' MD/ Angle @ top of window is 79 deg JEWELRY DETAIL No Depth Item 1 ±148' ST 2: 2-7/8" x 1" GLM w/ Dual Orifice 2 14,819' ST 3: 2-7/8" x 1" GLM w/ DV 3 ±4,971' 2-7/8" XN Profile -2.205" No -Go 4 ±4,982' Discharge Head -GPDIS S ±4,983' Pump -GPMTARI:1 6 ±5,004' Pump -GPMTAR3:1 7 ±5,011' Gas Separator - GRSFTX AR H6 8 ±5,015' Upper Tandem Sea] -GSB3DBUT AB/HSN PFSA 9 ±5,022' Lower Tandem Seal -GSB3DBLT AB/HSN FSA CLS 10 15,029' Motor -KMH: 25OHp/2,305V/60A 11 15,049' Pump Mate Sensor & Centralizer -±Bottom @ 5,055' 12 5,259' Liner Tie Back Sleeve 13 5,269' Baker ZXP Liner Top Packer 14 5,295' 4-1/2" Hook Hanger'LEM' Above Hanger 15 5,305' 4-1/2" Hook Hanger'LEM' Inside Hanger 16 5,322' Hook Wall Hanger Outside 17 5,425' Baker Liner Tie Back Sleeve 18 5,436, Baker ZXP Liner Top Packer 19 5,443' Baker HMC Liner Ha nger 20 5,459' 1 4.5" Non Locating Seal Assy. GENERALWELL INFO API: 50-029-23261-00-00 & 50-029-23261-60-00 Drilled and Cased by Doyon 14-5/26/2005 Revised By: TTW 2/1/2019 m; 4.54' 2.00' 21/16 5M Kill Line Valves 1199 BOPS Milne Point ASR Rig 1 BOPE 2019 Stripping Head nil, VBR or Pipe Ram—S I X111 „Ili- Blind 2 1/16 5M Choke Line Valves HCR Manual Manual HCR Updated 5/14/2018 HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: February 1st, 2019 Subject: Changes to Approved Sundry Procedure for Well MP E-32 Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. HAK Step Page Date Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date . . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0$ - 0 to$' Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: c¡ 0 (Count does include ~r sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: 7 / /0/07 If NO in stage 1 page(s) discrepancies were found: Organizing (done) D Two-sided 1111/111111 ""1111 REJCAN \z( Color Items: DIGITAL DATA ~iskettes, No. ~ D Other, No/Type: D Greyscale Items: D Poor Quality Originals: D Other: NOTES: Date 1// O/D 7 Date 1/10/07 ~ x30=foD Date: 7/'0 /07 BY: ~ Project Proofing BY: ~ Scanning Preparation BY: ,~ BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1/1111111111111111I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: VV1P /51 11111111111111" III /51 t11? +:lq = TOTAL PAGES ~q . (Count does not include cover shee6 III A 0 151 V Vrr 11111111111111" III NO YES /5/ ~ P NO /51 1111/111111111 1111I "111111I11111 "III /5/ Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page,doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 aos- e 2 December 30, 2011 p - 3 K Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ;t; ,.'s1tSaa Anchorage, Alaska 99501 .: °7f .�` Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, • Mehreen Vazir BPXA, Well Integrity Coordinator • 0 i t BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor , sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE -09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 ----- MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 ;l b J ~.-L_ DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Permit to Drill 2050650 Well Name/No. MILNE PT UNIT SB E-32 Operator BP EXPLORATION (ALASKA) INC MD 8894 /' TVD 4360 /' Completion Date 5/26/2005 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFRlCASANDRA, GYRO Well Log Information: >p~ d... ì I"U;. ~ It ~i- API No. 50-029-23261-00-00 Directional su~ - = (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH ~~- Asc Directional Survey 6520 8894 Open Asc Directional Survey 6520 8894 Open ~ 0 Asc Directional Survey 0 8045 Open 0 Asc Directional Survey 0 8045 Open ~ 0 Lis 13212 Induction/Resistivity 77 8836 Open ...R5t 13212 LIS Verification 77 8836 Open ø' 0 Lis 13213 Induction/Resistivity 77 7988 Open 2 13213 LIS Verification 77 7988 Open ED C Lis 13537 I nd uction/Resistivity 122 8894 Open - Received Comments 7/29/2005 IIFR 7/29/2005 MWD 7/29/2005 IIFR PB1 7/29/2005 MWD PB1 7/7/2005 7/7/2005 7/7/2005 7/7/2005 2/22/2006 ROP DGR EWR plus Graphics / PB 1 ROP DGR EWR 122-8045 plus Graphics Well Cores/Samples Information: e Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION y/e Daily History Received? B: Well Cored? Chips Received? .¥.LI:':l Formation Tops Analysis Received? ..:tL!i ~~-- Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Permit to Drill 2050650 Well Name/No. MILNE PT UNIT SB E-32 Operator BP EXPLORATION (ALASKA) INC MD 8894 Completion Date 5/26/2005 TVD 4360 Completion Status 1-01L Current Status 1-01L --.-------- !k Date: ~_._~ Compliance Reviewed By: API No. 50-029-23261-00-00 UIC N ÄJ ùl] ;2~~ ì -~-~ e e o . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 l?fj~l RE: MWD Fonnation Evaluation Logs MPE-32 + PB1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPE-32 + PB1: LAS Data & Digital Log Images: 50-029-23261-00, 70 dD~J- Dli5 1 CD Rom ~ g\ø9\cip · STATE OF ALASKA . ALASKA~LAND GAS CONSERVATION COMMTSslON WELL COMPLETION OR RECOMPLETION REPORT AND 4JQQ .. 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC25.105 20MC25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3984' FSL. 2032' FEL. SEC. 25. T13N, R10E, UM Top of Productive Horizon: 4247' FSL, 218' FEL, SEC. 25, T13N, R10E, UM Total Depth: 3911' FSL, 1643' FEL, SEC. 30. T13N, R11E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 569110 y- 6016521 Zone- ASP4 TPI: x- 570921 y- 6016800 Zone- ASP4 Total Depth: x- 574740 y- 6016502 Zone- ASP4 18. Directional Survey 0 Yes 181 No 21. Logs Run: MWD , GR . RES, IFRlCASANDRA , GYRO 22. One Other 5. Date Comp.. Susp., or Aband. 5/26/2005 6. Date Spudded 5/7/2005 7. Date T.D. Reached 5/17/2005 8. KB Elevation (ft): 56.04' 9. Plug Back Depth (MD+ TVD) 8894 + 4360 10. Total Depth (MD+TVD) 8894 + 4360 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" 10-314" 7-5/8" 4-1/2" x 4" GRADE H-40 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH NO HOLl; Top BOTTOM Top BOTTOM SI:!I: 35' 113' 35' 113' 42" 35' 2746' 35' 2661' 13-1/2" 33' 6299' 33' 4385' 9-7/8" 5425' 8894' 4467' 4360' 6-3/4" WT. PER FT. 92# 45.5# 29.7# 12.6# x 9.5# 23. Perforations op'en to Production (MD + TVD of TOE and Bottom Interval, Size and Number; if none, state 'none"): 4" Excluder Screens MD TVD MD 6303' - 8850' 4385' - 4361' 26. Date First Production: July 14, 2005 Date of Test Hours Tested 8/7/2005 12 Flow Tubing Casing Pressure Press. PRODUCTION FOR TEST PERIOD .. CALCULATED -11.. 24-HoUR RATE""" 24. SIZE 2-7/8",6.5#, L-80 TVD 25. 'A· UI~. 1· G ~ . ,1' ~- C~ Revision: 08M7~,~Štàrt Production 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 205-065 13. API Number 50- 029-23261-00-00 14. Well Name and Number: MPE·32 15. Field I Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 028231 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PULLED 260 sx Arctic Set (Approx.) 345 sx AS Lite, 371 sx Class 'G' 725 sx Class 'G' Excluder Screens TuelNG RECO~D DEPTH SET (MD) 5064' PACKER SET (MD) None DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude WATER-Bel o WATER-Bel o I GAS-Oil RATIO 269 Oil GRAVITY-API (CORR) CHOKE SIZE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Oil-Bel GAs-McF 834 224.5 Oil-Bel GAs-McF 1668 449 None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE RBDMS 8Ft AUG 232005 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe.d . S \~ ~ Title Technical Assistant { on~~ MPE-32 Well Number -~. 28, e GEOLOGIC MARKERS NAME MD TVD MA MB1 MB2 MC NA NB NC ND NE NF OA OA NF ND NC NC NC ND ND NC NC 4360' 4371' 4472' 4769' 4824' 4890' 4950' 5006' 5031' 5168' 5310' 5852' 5945' 6426' 6610' 6715' 6744' 6890' 8220' 8615' 8696' 4067' 4076' 4140' 4282' 4303' 4326' 4346' 4369' 4379' 4422' 4448' 4450' 4426' 4375' 4366' 4370' 4370' 4370' 4365' 4357' 4358' 30. List of Attachments: 205-065 Permit No. I Approval No. INSTRUCTIONS 29. . FORMATION TESTS Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None Date 0<6 -ll-oS Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IrEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). IrEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IrEM 20: True vertical thickness. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IrEM 27: If no cores taken, indicate "None". IrEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPE-32 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,520.80' MD 6,561.00' MD 8,894.00 I MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry..Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 (/1/ Date ) l/~\ Signed Þ~l rJ/JvJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 11-Jul-05 ) 0)'-- t, ~ }'. Ñ'¡~ . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well MPE-32 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,520.00' MD 6,561.00' MD 8,894.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ') l ~~\- 1LJ I\~' ,1/ ! Signed .' :, !)·IJJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 11-Jul-05 "Î 0 ,- 1\ I. \- ¡n::::=.¡ ^ .' ~ -Q Ii 1 ¡-L . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPE-32 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,045.00 I MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. AnChOrag~ AK 99518 !--1] '... . ¿9 /( '. Date '> l ~ ~\ Signed ~ jJ'\rV. Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 11-Jul-05 ~ 0 S- ---- 0 (g. ( f:;' l . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of SUNey Data for Well MPE-32 PB1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on SUNey: Window / Kickoff SUNey: Projected SUNey: 0.00' MD 0.00' MD 8,045.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date )1 ~h'r Signed íLJ- rJi0 Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 11-Jul-05 :< (}5-~'MJ-~ I-L . STATE OF ALASKA .. ALASKA :A.ND GAS CONSERVATION COMMI~N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3984' FSL, 2032' FEL, SEC. 25, T13N, R10E, UM Top of Productive Horizon: 4247' FSL, 218' FEL, SEC. 25, T13N, R10E, UM Total Depth: 3911' FSL, 1643' FEL, SEC. 30, T13N, R11E. UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569110 TPI: x- 570921 Total Depth: x- 574740 18. Directional Survey "y- 6016521' Zone- y- 6016800 Zone- y- 6016502 Zone- 181 Yes 0 No ASP4 ASP4 ASP4 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , GYRO 22. One Other 5. Date Comp., Susp., or Aband. 5/26/2005 ' 6. Date Spudded 5/712005 / 7. Date T.D. Reached 5/17/2005 / 8. KB Elevation (ft): 56.04' 9. Plug Back Depth (MD+ TVD) 8894 + 4360 10. Total Depth (MD+TVD) 8894 + 4360 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NIA MSL CASING SIZE 20" 10-3/4" 7-5/8" 4-1/2" x 4" GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTINGDEPTIi MD SETTING DEPTH TVD HOLE lOP BOTTOM Top BOTTOM SIZE 35' 113' 35' 113' 42" 35' 2746' 35' 2661' 13-1/2" 33' 6299' 33' 4385' 9-7/8" 5425' 8894' 4467' 4360' 6-314" WT. PER: FT. 92# 45.5# 29.7# 12.6# x 9.5# 23. Perforations op'en to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 4" Excluder Screens MD TVD MD 6303' - 8850' 4385' - 4361' 26. Date First Production: Not on Production Date of Test Hours Tested 24. SIZE 2-7/8",6.5#, L-80 TVD 25. 1b:Wall Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 205-065 13. API Number 50- 029-23261-00-00 14. Well Name and Number: MPE-32 15. Field I Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 028231 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PUllED 260 sx Arctic Set (Approx.) 345 sx AS Lite, 371 sx Class 'G' 725 sx Class 'G' Excluder Screens DEPTH SET (MD) 5064' PACKER SET (MD) None DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): PRODUCTION FOR TEST PERIOD .. CALCULATED ....... 24-HoUR RATE""'" Oil -BSl Flow Tubing Casing Pressure Press. Oll-Bsl 27. GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". GAs-McF W A TER-BSl None RBDMS 8Ft "" f! "1 ?nOli RBDMS BFL JUL 0 7 2005 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~,j¡0E~~6:¡ ¡ S-~ ~'.:: Ó ç¡ Ib .c,iÇ 1 ----lfT'1(,,> I ......."...) . ". """"'.jf" .. ~ -''>/1/ ~ .~ i ---A..------l !.-._.._.._.._-~.._. &t- G 28. ' GEOLOGIC MARKERS . NAME MD TVD MA MB1 MB2 MC NA NB NC ND NE NF OA OA NF _ ND NC NC NC ND ND NC NC 4360' 4371' 4472' 4769' 4824' 4890' 4950' 5006' 5031' 5168' 5310' 5852' 5945' 6426' 6610' 6715' 6744' 6890' 8220' 8615' 8696' 4067' 4076' 4140' 4282' 4303' 4326' 4346' 4369' 4379' 4422' 4448' 4450' 4426' 4375' 4366' 4370' 4370' 4370' 4365' 4357' 4358' 29. .ATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and, correct to the best of my knowledge. Signed son~0 ~Title Technical Assistant DateOl-O\-O)" MPE-32 205-065 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Walter Quay, 564-4178 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ 2-9/16" - SM FMC Wellhead: 11"X7-1/16"SM. Gen SA, W 2-7/8" FMC Tbg. .,3" LH Acme on top and 2-7/8" EU 8rd on bottom, 2.S" CIW BPV Profile ~ 20" x 34" insulated, 215 #/ft A-53 D:IÐ 103/4" 45.5 ppf L-80 BTC-M (Drift 10 = 9.794, cap. = .0961 bpf) 103/4" HOWCO Float Shoe I 2744' I ~ 75/8" 29.7 ppf, L-80, BTRC-mod casing (Drift 10 = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) KOP @ 450' +60 degree from 750' Tbg max angle = 69 degree @ 4750' Window in 7 5/8" Casing @ 5310' - 5322' Well Angle @ window = 79° Baker Hook Wall Hanger inside 7-5/8" Window 16.70' Baker Hook Wall Hanger outside 7-5/8" Window 6.15' Baker Tie Back Sleeve 5259' Baker ZXP Liner Top Packer 5269' Baker LEM top 5295' Baker Non-locating Seal Assembly 5459' 75/8" x 10' Pup Joint 5332' - 5342' Baker Tie Back Sleeve 5425' Baker ZXP Liner Top Packer 5436' Baker 7-5/8" x 5" HMC Liner Hanger 5443' Baker 190-47 Seal Bore Extension 5449' 7-5/8" Weatherford Float Collar 6214' ~ 7-5/8" Weatherford Float Shoe 6299' DATE S/25/05 REV,BY L. Hulme COMMENTS Drilled & Completed by Doyon 14 MPE-32 {II} OA Lateral ~ Orig. KB elev. = 57.70' (Doyon 14) Orig. .S. elev.= 30.30' (Doyon 14) L HES TMPD 2-7/8" x 1" Gas Lift Mandrel 148'1 .. HES TMPD 2-7/8" x 1" Gas Lift Mandrel 2018' HES TMPD 2-7/8" x 1" 4819' Gas Lift Mandrel HES XN-Nipple (2.250" id) 4971 ' Discharge Head 4993' Tandem ESP Pump GMPTAR 1:1 4993' 122GC2200 & 19GC8200 Gas Separator 5021' I Model - GRSFTXAR H6 Tandem Seal Section 5025' I Model - GSB3 DB UT/L TAB HSN PFSAlPSA Motor, 228 KMH I 03 ' I 2305 volt I 60 amp 5 9 PumpMate wI 6 tin Centralizer I 5059' I PumpMate Depth = 3260' TVD ~ ~ 85 jts, - 41/2" 12.6# L-80, IBT Slotted Liner (5331' - 8851 ') 6 1/8" Hole td @ 8922' HES 41/2" "V" Float Shoe 8894 ' 6 1/8" Hole td @ 8894' HES 4 1/2" "V" Float Shoe 8894 ~ \ \.. NC/ND Lateral 37 jts. - 4", 9.5# L-80, IBT ~ 37 jts Baker Excluder Screens (6203' - 8849') MILNE POINT UNIT WELL MPE-32 API NO: 50-029-23261-00 API NO: 50-029-23261-60 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5/7/2005 End: 5/7/2005 00:00 - 01 :30 1.50 MOB P PRE PJSM, Skid rig floor 01 :30 - 03:30 2.00 MOB P PRE PJSM, Move rig to MPE-32, spot over well 03:30 - 04:00 0.50 MOB P PRE PJSM, skid rig floor. spot rockwasher 04:00 - 05:00 1.00 MOB P PRE PJSM, Berm rockwasher, spot water tank, hook up lines to floor, Rig accepted @ 05:00 5/7/2005 05:00 - 08:30 3.50 RIGU P PRE PJSM, Nipple up Diverter and lines, Derrick inspection, load pipe shed 08:30 - 09:30 1.00 RIGU P PRE PJSM, prep rig floor, move pipe in derrick, fill pits with spud mud 09:30 - 10:00 0,50 RIGU P PRE PJSM, Pick up HWT pipe and jars stand in derrick 10:00 - 12:30 2.50 RIGU P PRE PJSM, Picking up BHA 12:30 - 13:30 1.00 RIGU P PRE PJSM, Pre-spud meeting with crews, Diverter test, the right to witness test was waver by John Crisp AOOGC 13:30 - 14:00 0.50 DRILL P SURF PJSM, fill hole with mud check for leaks, wash out to 115' 14:00 - 14:30 0.50 DRILL P SURF PJSM, Drilling 115' to 179' 14:30 - 15:00 0.50 DRILL P SURF PJSM, POH, rig up wire line Gyro unit 15:00 - 15:30 0.50 DRILL P SURF PJSM, Pickup BHA 15:30 - 00:00 8.50 DRILL P SURF Drilling 179' to 1011' with 500 gpm, 1400 psi, 65 rpms, run Gyros to 450', AST 1.79, ART 4.07, TQ 4K 5/8/2005 00:00 - 07:00 7.00 DRILL P SURF Drilling 1011' to 1776" with 540 gpm, 2000 psi, 65 rpms, rerun Gyro @ 1200' 07:00 - 08:30 1.50 DRILL P SURF Circ. three bottoms up, with 535 gpm 2100 psi 80 rpms 08:30 - 09:00 0.50 DRILL P SURF PJSM, Pump out of hole to Hwdp 09:00 - 09:30 0.50 DRILL P SURF PJSM, Rih, wash last stand to bottom 09:30 - 11 :00 1.50 DRILL P SURF PJSM, Circ and raise mud wt to 9.8 with spike mud 11 :00 - 18:30 7.50 DRILL P SURF Drilling 1776' to 2756 with 550 gpm, 2500 psi, 80 rpms, Ast 2.32, Art 7.35, Tq 5K, had Hydrates from 2260 to 2408' 18:30 - 20:00 1,50 CASE P SURF Circ, Two bottoms up with 550 gpm, 2300 psi, 80 rpms 20:00 - 22:00 2.00 CASE P SURF PJSM, Pump out to Hwdp 22:00 - 22:30 0.50 CASE P SURF PJSM, Rih wash last stand to bottom 22:30 - 00:00 1.50 CASE P SURF Circ, Three bottoms up with 550 gpm, 2300 psi, 80 rpms 5/9/2005 00:00 - 00:30 0.50 CASE P SURF Finish Circ. Three bottoms up 00:30 - 02:00 1.50 CASE P SURF PJSM, Pumping out to Hwdp with full drilling rate 02:00 - 04:30 2.50 CASE P SURF PJSM, Stand back Hwdp, lay down BHA 04:30 - 05:30 1.00 CASE P SURF PJSM, Rig up to run Csg 05:30 - 10:00 4.50 CASE P SURF PJSM, Picking up 103/445# 1-80 Btc csg, total of 65 jts run, broke circ @ 1435', landed csg, shoe @ 2746', Float 2663' 10:00 - 10:30 0.50 CASE P SURF PJSM, Rig down Franks tool, rig up cement head 10:30 - 12:30 2.00 CASE P SURF Circ, with 6 bbls min 200 psi, thin mud for cement job" PJSM on cementing 12:30 - 16:00 3.50 CEMT P SURF Cement with Schumberger with 5 bbls water, test lines to 2500 psi,S bbls water,68 bbls 10.3 mud push, drop bottom plug,345 sx(277 bbls), type ASL yield 4.44, mixed @ 10.7, tailed with 371 sxs(77 bbls), Class G, yield 1.17, mixed @ 15.8, drop top plug, kicked out with 30 bbls water, displace with rig 6 bbls min. 226 bbls 9.8 mud, bump plug with 1700 psi, full returns thru out job, 166 bbls good cement to surface, cement job was mixed and displaced @ 6 bbls min., float held 16:00 - 17:00 1.00 CASE P SURF PJSM, Flush Diverter, lay down landing jt, nipple down diverter 17:00 - 18:00 1,00 CASE P SURF PJSM, Clear floor of Csg tools, change out Bales 18:00 - 19:00 1,00 CASE P SURF PJSM, Nipple up FMC Casing head and test to 1000 psi for 10 min. 19:00 - 22:30 3.50 CASE P SURF PJSM, Nipple up BOPS, rig up to test Printed: 5/31/2005 8:03:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 5/4/2005 5/26/2005 Spud Date: 5/7/2005 End: 5/9/2005 22:30 - 00:00 1.50 CASE P SURF PJSM, Test BOPS and Manifold to 250-3500 psi for 5 min. per test, Hydrill 250-2500 psi for 5 min. per test, the right to witness test was wavier by John Crisp AOOGC, witness by WSL, Hunting and repairing leaks, one leak on manifold packing, one leak on valve to test pump, replace valve 5/1 0/2005 00:00 - 08:00 8.00 CASE P SURF PJSM, Testing BOPS and Manifold to 250-3500 psi for 5 min. per test, Hydrill 250-2500 psi for 5 min. per test, witness by WSL, Hunting and repairing leaks, one leak on manifold packing, one leak on valve to test pump, replace valve, change 2 7/8" x 5" VBR's to 4" solid rams 08:00 - 09:00 1.00 CASE P SURF Rig down test equipment - Pull test plug - Install wear ring - Close annulus valves - Change bails - Shuffle HWT 09:00 - 12:00 3.00 CASE P SURF Pick up 87 joints 4" DP from pipe shed - POH standing back same 12:00 - 14:30 2.50 CASE P SURF PJSM - Make up BHA - Bit - motor - MWD - Orient - Flex DC's - HWT - Change out 5" Handling tools to 4" 14:30 - 15:00 0.50 CASE P SURF Surface test MWD 15:00 - 16:00 1.00 CASE P SURF Con't RIH with 4" DP to 2663' - Wash last stand to F/C 16:00 - 17:00 1.00 CASE P SURF Circulate String vol - GPM 400 - PP 1270 17:00 - 18:00 1,00 EVAL P SURF Rig up test equip - Test Casing to 1000 psi for 30 mins - Rig down test equip 18:00 - 19:30 1.50 DRILL P SURF Drill float collar - Shoe trac - Shoe - 20' new hole from 2756' to 2776' 19:30 - 20:00 0.50 CASE P SURF CBU 1 X - GPM 420 - PP 1270 20:00 - 20:30 0,50 CASE P SURF Displace well with 9 ppg LSND mud 20:30 - 21 :30 1.00 EVAL P SURF Rig up testing equipment - Perform FIT - MD 2746' - TVD 2661 - Mud weight 9 ppg - Surface pressure 280 = EMW 11 ppg - Rig down testing equipment - Blow down choke manifold 21 :30 - 22:30 1.00 DRILL P INT1 Drill from 2776' to 2918' - No MWD detection 22:30 - 23:00 0.50 DRILL N DFAL INT1 Pump out from 2918' to 2740' - Flow check well - Well static - Pump dry job 23:00 - 00:00 1.00 DRILL N DFAL INT1 POOH from 2740' to 712' 5/11/2005 00:00 - 01 :00 1.00 DRILL N DFAL INT1 Stand back HWT - DC's - Drain motor - Inspect bit 01 :00 - 01 :30 0.50 DRILL N DFAL INT1 Download MWD - Check electrodes on TM - OM - HOC - Broken connection between the OM / HOC - Change out 01 :30 - 03:00 1.50 DRILL N DFAL INT1 Program MWD - Orient motor - MWD - MU DC's 1st stand HWT - Test MWD - MWD failed incorrect data from directional tool 03:00 - 04:30 1.50 DRILL N DFAL INT1 Stand back HWT - DC's - Drain motor - Download MWD - C/O OM HOC 04:30 - 06:00 1.50 DRILL N DFAL INT1 Program MWD - Orient motor - MU DC's - 1 std HWT - Surface test MWD - MU HWT - Jars 06:00 - 07:00 1.00 DRILL N DFAL INT1 RIH from 712' to 2918' - Wash last stand to bottom - Survey @ 2822' 07:00 - 14:00 7.00 DRILL P INT1 Directional Drill from 2918' to 3968' - WOB 10 to 20 - RPM 80- TO on 5 - off 3 - GPM 525 - PP on 2540 - off 2350 - PU 130- SO 110 - ROT 120 14:00 - 15:00 1.00 DRILL P INT1 CBU - GPM 575 - PP 2740 - RPM 80 - TO - Flow check - Well static 15:00 - 16:00 1.00 DRILL P INT1 Pump out to shoe from 3968' to 2740' - GPM 525 - PP 2744 16:00 - 17:30 1,50 DRILL P INT1 CBU at shoe - Massive clay balls - Plugged flow line - GPM 500 - PP 1670 psi - RPM 40 17:30 - 18:30 1.00 DRILL P INT1 Cut drlg line - Rig service - Top drive service Printed: 5/31/2005 8:03:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5/7/2005 End: 5111/2005 18:30 - 19:30 1.00 DRILL P INT1 RIH from 2740' to 3968' - Precauctionary wash last stand to bottom 19:30 - 00:00 4.50 DRILL P INT1 Directional Drill from 3702' to 4351 - WOB 10 to 30 - RPM 80- TO on 5k - off 3k - GPM 530 - PP on 2680 - off 2460 - PU 137- SO 110 - ROT 126 5/12/2005 00:00 - 00:00 24.00 DRILL P INT1 Directional Drill 9 7/8" hole from 4351' to 5997' - WOB 10 to 30 - RPM 80 to 90 - TO on 8 - off 5 - GPM 550 - PP on 3270 - off 3140 - PU 128 - SO 95 - ROT 110 - Top "OA" sand 5310' MD 4448' TVD - Fault 5617' 5/13/2005 00:00 - 08:00 8.00 DRILL P INT1 Directional Drill from 5997' to 6310' - TO 9 7/8" Hole - WOB 10 to 30 - RPM 80 - TO on 8 - off 6 - GPM 530 - PP on 3500 - off 3260 - PU 120 - SO 85 - ROT 105 08:00 - 09:30 1.50 CASE P INT1 CBU 2 X - GPM 555 - PP 3300 - RPM 80 - TO 6 - Flow check - Well static 09:30 - 13:00 3.50 CASE P INT1 Pump out from 6310' to 2740' - GPM 525 - PP 2980 13:00 - 14:00 1,00 CASE P INT1 CBU 1 X - GPM 525 - PP 2230 14:00 - 15:30 1.50 CASE P INT1 RIH from 2740' to 6310' - Hit tight hole @ 4000' to 4100' - work through without pump or rotation 15:30 - 17:30 2.00 CASE P INT1 CBU 3 X - GPM 550 - PP 3420 - RPM 80 - T06 - Flow check - Well Static 17:30 - 21 :00 3,50 CASE P INT1 Pump out form 6310' to 2740' - GPM 525 - PP 2500 21 :00 - 22:00 1.00 CASE P INn CBU 1 X - GPM 525 - PP 2000 - Flow Check - Well Static - Pump dry job 22:00 - 23:00 1.00 CASE P INT1 POH from 2740' to 712' to BHA 23:00 - 00:00 1.00 CASE P INn LD 5" HWT 5/14/2005 00:00 - 01 :00 1.00 CASE P INT1 Con't Lay down BHA 01 :00 - 01 :30 0.50 CASE P INT1 Pull wear ring - Install test plug 01 :30 - 03:00 1.50 CASE P INT1 Change top rams to 7 5/8" casg rams - Test door seals to 1500 psi for 5 mins - 03:00 - 04:00 1.00 CASE P INT1 Rig up casg tools to run 7 5/8" casg 04:00 - 07:00 3.00 CASE P INT1 PJSM - PU I Run 7 5/8" L-80 - BTC-M - 29.7# casing to shoe 2740' 07:00 - 07:30 0.50 CASE P INT1 Circ casg vol 124 bbls 6.5 bpm @ 400 psi PU 125 SO 115 07:30 - 10:30 3.00 CASE P INT1 Con't RIH with 7 5/8" casg to 6260' 10:30 - 11 :30 1.00 CASE P INT1 PU landing joint - Circ casging volume - Staging up pumps from 2 bpm to 6.5 bpm ICP 520 - FCP 450 - PU 250 - SO 130 11 :30 - 12:00 0.50 CASE P INT1 Land casg - (Float shoe @ 6299' - Float collar 6214') - LD franks fill up tool - RU Cementing head and lines 12:00 - 13:00 1.00 CASE P INT1 Can't circ casg reciprocate pipe 13:00 - 15:00 2.00 CEMT P INT1 Give to Dowell Schlumberger Pump 5 bbls water Test lines to 3000 psi 15 bbls CW-100 50 bbls Mud Push Mixed @ 10.5 ppg Drop bottom plug 150 bbls - 725 sxs 1.16 cf/sx 15.8 ppg Class "G" cement Drop top plug Displace with 287 bbls Oil Base Mud 9.2 ppg Bump plug with 2000 psi - 1000 over circulating pressure Hold for 3 mins - Bleed off pressure floats holding 15:00 - 16:00 1.00 CASE P INT1 Blow down lines - Remove cementing head I lines 16:00 - 17:00 1.00 CASE P INT1 RU 1" hydrill pipe to 7 5/8" blow down head - Void 75/8" casing to 60' - Clear rig floor of casg I cementing equipment - LD Printed: 5/31/2005 8:03:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5/7/2005 End: 5114/2005 16:00 - 17:00 1.00 CASE P INT1 same 17:00 - 17:30 0.50 CASE P INT1 Flush well head & stack with 40 bbls water - Drain stack - LD landing joint 17:30 - 18:00 0.50 CASE P INT1 Install FMC 7 5/8" casing Pack-off - Test to 5000 psi for 10 mins 18:00 - 19:00 1.00 CASE P INT1 Clear rig floor of cementing and casg running tools 19:00 - 20:30 1.50 CASE P INT1 Change casg rams to VBR 2 7/8" x 5" - Install test plug - test to 250 low 3500 high 5 mins each test - Record on chart· Pull test plug - Install wear ring - Close annulus valves 20:30 - 21 :00 0.50 CASE P INT1 Inject 40 bbls water in "OA" at 2 bpm 950 psi for 15 bbls increase to 3 bpm 1040 psi - shut down 750 psi final pressure 21 :00 - 23:30 2.50 CASE P INT1 Mobilize BHA - MU bit - Motor with 1.5 degree bend - Stab - MWD - Orient same - Flex DC's - Jar - Surface test MWD 23:30 - 00:00 0,50 CASE P INT1 RIH with 4" DP 5/15/2005 00:00 - 02:30 2.50 CASE P INT1 RIH to 5773' tag cement stringers 02:30 - 03:30 1.00 CASE P INT1 Break Circulation - Wash I Ream from 5770' to 6155' 03:30 - 04:30 1.00 CASE P INT1 Rig up test equip - Test casg to 2500 psi for 30 mins - Record on chart - Rig down test equip 04:30 - 06:00 1.50 CASE P INT1 Cut Drlg line - Rig service - Top drive service 06:00 - 07:00 1.00 DRILL P INT1 Drill Float collar @ 6214' - Shoe trac - Float shoe 6299' - Clean out rat hole from 6299' to 6310' - Drill 20' new hole from 6310' to 6330' - RPM 30 - TO 2 - GPM 272 - PP 2660 off - on 2840 - WOB5to 10 07:00 - 08:00 1.00 CASE P INT1 CBU - Condition mud for FIT - 80 RPM - GPM 272 - PP 2690 - (Freeze protect OA with 100 bbls diesel - 2 to 3 bpm @ ICP 1050 - FCP 750 - Shut in with 750 psi) 08:00 - 09:00 1.00 EVAL P INT1 Rig up testing equip· Perform FIT - MD 6299 - TVD 4386 - MW 9 - Surface pressure 684 = EMW 12.0 - Rig down test equip - Blow down manifold I lines 09:00 - 12:00 3.00 DRILL P PROD1 Directional Drill NCIND Lateral from 6330' to 6680' - WOB 2 to 10 - RPM 80 - TO on 2.5 - off 2 - GPM 272 - PP on 2930 - off 2810 - PU 120 - SO 88 - ROT 105 12:00 - 13:00 1.00 DRILL P PROD1 Circulate per Geologist 13:00 - 23:00 10.00 DRILL P PROD1 Directional Drill NCIND Lateral from 6680' to 7504' - WOB 2 to 10 - RPM 80 - TO on 3 - off 3 - GPM 272 - PP on 2990 - off 2850 - PU 120 - SO 85 - ROT 105 23:00 - 00:00 1.00 DRILL P PROD1 Circulate per Geologist 5/16/2005 00:00 - 06:30 6.50 DRILL P PROD1 Directional Drill From 7504' to 8045' - WOB 2 to 5 - RPM 80 - TO on 4 - off 3 - GPM 272 - PP on 3140 - off 3010 -PU 125- SO 75 - ROT 105 06:30 - 08:30 2.00 DRILL P PROD1 CBU 3 X - Clean up hole for open hole side tract - RPM 80 - TO 3.5 - GPM 300 - PP 3550 08:30 - 13:00 4.50 DRILL P PROD1 Pump out from 8045' to 6830' - Packing off . Back ream at 40 rpm gpm 275 - PP 2700 from 6830 to 6660' - Con't pump out rotating @ 40 RPM to 5300' @ 285 gpm - 2460 psi - 40 rpm 13:00 - 13:30 0.50 DRILL P PROD1 CBU 1 X - GPM 275 - PP 2460 psi - RPM 40 13:30 - 14:00 0.50 DRILL P PROD1 RIH from 5300' to 6600' - Wash last stand to bottom 14:00·17:00 3.00 DRILL C PROD1 Build trough for open hole sidetract @6561' to 6638' 17:00 - 17:30 0.50 DRILL C PROD1 Directional Drill from 6561' to 6716' - WOB 2 to 5 . RPM 80 - TO on 4 - off 3 - GPM 272 - PP on 3100 - off 3000 -PU 120- SO 85 - ROT 105 17:30 - 18:00 0.50 DRILL C PROD1 Circulate per Geolgist Printed: 5/31/2005 8:03:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5/7/2005 End: 5116/2005 18:00 - 00:00 6.00 DRILL C PROD1 Directional Drill from 6716' to 7215' - WOB 2 to 5 - RPM 80- TO on 4 - off 3 - GPM 284 - PP on 3090 - off 2950 -PU 116- SO 85 - ROT 105 5/17/2005 00:00 - 20:59 20.98 DRILL C PROD1 Directional Drill from 7215' to 8894' - T.D. 63/4" NCIND Lateral - WOB 2 to 5 - RPM 80 - TO on 5 - off 4 - GPM 275 - PP on 3180 - off 2990 - PU 126 - SO 75 - ROT 105 20:59 - 21 :00 0.02 DRILL X MISC PROD1 For DIMS Score 21 :00 - 23:00 2.00 CASE P PROD1 CBU 3 X - GPM 325 - PP 3550 - RPM 90 - TO 5 - Flow check - Well static 23:00 - 00:00 1.00 CASE P PROD1 Pump out from 8894' to 7748' - GPM 300 - PP 2980 5/18/2005 00:00 - 03:30 3.50 CASE P PROD1 Con't pump out from 7748' to 6800' - Packing off - Back ream from 6800' to 6500' - Packing-off some stalling on rotary - pull slow - Back ream from 6500 to 6300' - No packing off hole better - Con't rotating @ 40 RPM and pumping to 5300' 03:30 - 04:30 1.00 CASE P PROD1 CBU 2 X - Lots shale over shakers - GPM 325 - PP 2900 - RPM 40 - TO 2 04:30 - 06:00 1.50 CASE P PROD1 RIH from 5300' to 6734' - Check shot survey to confirm in correct hole - Correct hole - Con't RIH from 6734' to 8894' 06:00 - 08:00 2.00 CASE P PROD1 CBU3 X - GPM 325 - PP 3620 - RPM 80 - TO 3 - Change screen on shakers from 200 mesh to 230 mesh after 1 st bottoms up 08:00 - 11 :30 3.50 CASE P PROD1 Pump out hole @ GPM 325 - Back ream from the shoe to 5300' at 40 RPM to help clean up cuttings bed in casing 11 :30 - 13:00 1.50 CASE P PROD1 Flow check - Well static - CBU 2 X - GPM 300 - PP 2850 - RPM 40 - Flow check - Well static - Pump dru job 13:00 - 13:30 0.50 CASE P PROD1 Bust Ice out of Derrick 13:30 - 14:30 1.00 CASE P PROD1 POH from 5300' to 2230' 14:30 - 16:00 1.50 CASE P PROD1 Repair hydralic hose on top drive 16:00 - 16:30 0.50 CASE P PROD1 Con't POOH from 2230' to BHA 16:30 - 18:00 1.50 CASE P PROD1 Stand back Flex DC's - LD Jar - MWD - Stab - Break bit - Flush motor - LD motor 18:00 - 19:30 1.50 CASE P PROD1 Clear rig floor - RU Liner handling tools - 19:30 - 23:30 4.00 CASE P PROD1 PJSM - PU 4" screen liner - 23:30 - 00:00 0.50 CASE P PROD1 Make up Baker HMC hanger - Baker ZXP packer - Liner weight 42K 5/19/2005 00:00 - 01 :00 1.00 CASE P PROD1 Con't make up Liner hanger and ZXP Packer - Liner weight 42K 01 :00 - 02:30 1,50 CASE P PROD1 RIH with liner to 7 5/8" shoe @ 6290' - Break Circulation 02:30 - 04:00 1.50 CASE P PROD1 Con't RIH with 4" Liner on 4" DP from 6290' to 8894' 04:00 - 05:00 1.00 CASE P PROD1 Drop ball - Pump ball down @ 3 bpm 590 psi for 390 stks - Slow to 1.5 bpm 320 psi - Ball on seat 440 stks pumped - Pressure up to 2000 psi - Slack off 40K - Pressure up to 3800 psi - Bleed off - Pressure up to 3900 psi - Bleed off - Close Annular - Pressure up annulus to 1500 psi hold 2 mins - No pressue on DP - Bleed off - PU 20 - Rotate 20 turns to the right - 1 turn back - Pick up lost 10K - Liner released 05:00 - 06:00 1,00 CASE P PROD1 CBU 1 X - GPM 300 - PP 1100 - No rotation or reciprocating - Flow check - Well static 06:00 - 08:00 2.00 CASE P PROD1 POH with Baker running tools 08:00 - 09:00 1.00 CASE P PROD1 Lay down liner running tool - Clean rig floor 09:00 - 10:00 1.00 STWHIP P PROD2 Pick up 4 3/4" drill collars - 4" HWT - RIH - Pump 6.5 bpm @ 400 psi - To clear drill string 10:00 - 11 :00 1.00 STWHIP P PROD2 Stand back drill string in derrick Printed: 5/31/2005 8:03:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5f7/2005 End: 5119/2005 11 :00 - 14:00 3.00 STWHIP P PROD2 Pick up I make up Baker 7 518" whipstock assembly - whipstock - slide - upper I lower starting mills - MWD - Orient - Bumper sub - Surface test MWD - Con't make up DC's - HWT 14:00 - 17:00 3.00 STWHIP P PROD2 RIH with whipstock to 5425' - Fill every 25 stands 17:00 - 17:30 0.50 STWHIP P PROD2 Orient whipstock to 15 degree left of high side - PU 120 - SO 105 - ROT 110 17:30 - 22:00 4.50 STWHIP P PROD2 Milling window - TOW 5310' - BOW 5322' - Drlg from 5322' to 5336' - WOM - 2 to 8 - RPM 70 to 110 - TO 3 to 6 - GPM 300 - PP 2150 22:00 - 23:00 1.00 STWHIP P PROD2 CBU - Pump hi-vis sweeps - Work mills through window - RPM 120 - Flow check - Well static 23:00 - 00:00 1.00 STWHIP P PROD2 Pull 5 stands filling with trip tank From 5310' to 4850' - Check for swab I proper hole fill - Pump dry job 5/20/2005 00:00 - 01 :30 1.50 STWHIP P PROD2 POH from 4850' to 860' @ BHA - Stand back DC's - HWT 01 :30 - 02:30 1.00 STWHIP P PROD2 LD MWD - Whipstock milling tools - Top mill in gauge 6 3/4" 02:30 - 03:30 1.00 STWHIP P PROD2 Pull wear ring - Flush BOPs - Re-install wear ring 03:30 - 04:00 0.50 STWHIP P PROD2 Clear I Clean rig floor 04:00 - 05:00 1.00 STWHIP P PROD2 MU 63/4" drlg BHA - PU Bit - Motor - MWD - Orient 05:00 - 07:00 2.00 STWHIP P PROD2 Upload MWD - Surface test MWD - GPM 285 @ 2000 07:00 - 07:30 0.50 STWHIP P PROD2 Load Nukes - RIH with Flex DC's - Jars 07:30 - 09:30 2.00 STWHIP P PROD2 RIH to 5200' - Fill every 25 stands 09:30 - 11 :00 1.50 STWHIP P PROD2 Cut drlg line - Top drive service - Rig service 11 :00 - 11 :30 0.50 STWHIP P PROD2 Orient motor - Slide through window with out pumps on 11 :30 - 00:00 12.50 DRILL P PROD2 Directional Drill "OA" Lateral from 5336' to 6385' - WOB 2 to 6 - RPM 80 to 85 - TO on 4 - off 3 - GPM 300 - PP on 3200 - off 2980 - PU 120 - SO 95 - ROT 110 5/21/2005 00:00 - 11 :30 11.50 DRILL P PROD2 Directional Drill from 6385' to 7426' - WOB 6 to 7 - RPM 80- TO on 4 - off 3.5 - GPM 288 - PP on 3200 - off 3130 - PU 118 - SO 85 - ROT 105 11 :30 - 13:00 1.50 DRILL P PROD2 CBU 2 X - GPM 285 - PP 3260 - RPM 80 - TO 3.5 - Flow check - Well static 13:00 - 15:00 2.00 DRILL P PROD2 Pump out from 7426' to 5346' - Pump at drlg rate - Pull thru window with out pumping or rotating to 5282' - Flow check - Hole static 15:00 - 15:30 0.50 DRILL P PROD2 CBU 1 X - GPM 297 - PP 3000 - RPM 40 - TO 1.5K 15:30 - 16:00 0.50 DRILL P PROD2 Rig service - Top drive - Crown section - Travelling blocks - Drawworks 16:00 - 17:00 1.00 DRILL P PROD2 RIH 5282' to 7330' - (No pump or rotating going thru window) - Precauctionary wash from 7330' to 7426' 17:00 - 00:00 7.00 DRILL P PROD2 Directional Drill from 7426' to 8002' - WOB 2 to 4 - RPM 80 - TQ on 4 - off 4 - GPM 285 - PP on 3440 - off 3130 - PU 126- SO 85 - ROT 107 5/22/2005 00:00 - 11 :30 11.50 DRILL P PROD2 Directional Drill 6 3/4" from 8002' to 8922' - TO "OA" Lateral - (98.7% net to gross - Total pay drilled 3568' - Non pay 44' Out at TOA at TO) - WOB 2 to 5 - RPM 80 - TO on 5 - off 4 - GPM 285 - PP 3340 - off 3180 - PU 126 - SO 75 - ROT 106 11 :30 - 13:00 1.50 CASE P PROD2 CBU 2 X - GPM 297 - PP 3550 - RPM 80 - TO 4 13:00 - 14:00 1.00 CASE P PROD2 Pump out from 8922' to 7426' - Pump out @ drlg rate 14:00 - 15:00 1.00 CASE P PROD2 CBU 1 X - GPM 297 - PP 3300 - RPM 80 - TO 3.5 15:00 - 15:30 0.50 CASE P PROD2 RIH from 7426' to 8870' - Precauctionary wash from 8870' to 8922' 15:30 - 18:00 2,50 CASE P PROD2 CBU 3 X - GPM 297 - PP 3550 - RPM 80 - TO 4 18:00 - 21 :00 3.00 CASE P PROD2 Pump out from 8922' to 5346' - Pump at drlg rate - Pull thru Printed: 5/31/2005 8:03:16 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5/7/2005 End: 5122/2005 18:00 - 21 :00 3.00 CASE P PROD2 window with out pump or rotation from 5346' to 5282' 21 :00 - 22:00 1.00 CASE P PROD2 CBU 1 X - GPM 297 - PP 3300 - RPM 40 - TQ 2 - Flow check - Well static - Pump dry job 22:00 - 00:00 2.00 CASE P PROD2 POH from 5280' to BHA @ 235' 5/23/2005 00:00 - 01 :00 1.00 CASE P PROD2 LD BHA - Flex Dc's· Jars 01 :00 - 01 :30 0.50 CASE P PROD2 Down-load Nukes - Down load MWD 01 :30 - 02:30 1.00 CASE P PROD2 LD MWD - Stab - Break bit - Flush motor - LD motor 02:30 - 03:00 0.50 CASE P PROD2 PU Baker Whipstock retrieving assy - MWD 03:00 - 03:30 0.50 CASE P PROD2 Up-load MWD 03:30 - 04:30 1.00 CASE P PROD2 Orient - Surface test - Con't MU and RIH with BHA 04:30 - 06:30 2.00 CASE P PROD2 RIH with whipstock retrieving assy from 750' to 5280' - Filling every 25 stands 06:30 - 07:00 0.50 CASE P PROD2 Pump 285 GPM @ 1800 psi - Orient hook 15 degree to left of high side - Latch onto whipstock - Pull free with 70K overpull - PU118-S0108 07:00 - 07:30 0,50 CASE P PROD2 CBU 285 GPM @ 1800 psi - Flow check 07:30 - 09:30 2.00 CASE P PROD2 POH with whipstock 09:30 - 11 :00 1.50 CASE P PROD2 LD Whipstock - Retrieving tools 11 :00 - 12:00 1.00 CASE P PROD2 Clear rig floor 12:00 - 12:30 0.50 CASE P PROD2 RU to run 4 1/2" slotted liner 12:30 - 15:30 3.00 CASE P PROD2 PJSM - PU I Run 4 1/2" L-80 12.6# IBT-M Slotted liner 15:30 - 16:00 0.50 CASE P PROD2 Make up Baker hook as per Baker Tech - PU 90K - SO 85K - Block 50K 16:00 - 17:00 1.00 CASE P PROD2 RIH with 41/2" Slotted liner on 4" DP to TOW 5310' - PU 108' SO 1 00 17:00 - 20:00 3,00 CASE P PROD2 Con't RIH thru window to 8903' shoe depth - 3 Attempts to hook liner - Stack 0 to 25K on hook three times @ 5322' - un-hook liner - RIH 10 below lower window slot - 5322' - to 5332' - Pull back up and re-hook liner @ 5322' to verify good hook - Stack out 30K twice at 5322' 20:00 - 21 :30 1.50 CASE P PROD2 Drop ball 29/32" - Pump 3 pipe volume - No Indication of ball on seat - Drop 1 112" ball - Pump ball on seat - Pressure up to 3500 psi release off hook - Pull 2 stands - Lost 15K string weight 21 :30 - 23:30 2.00 CASE P PROD2 Cut drlg line - Rig service - Top drive service 23:30 - 00:00 0.50 CASE P PROD2 POH - Wet 5/24/2005 00:00 - 02:00 2.00 CASE P PROD2 POH with 4 1/2" liner running tool 02:00 - 02:30 0.50 CASE P PROD2 LD Baker running tool 02:30 - 03:00 0.50 CASE P PROD2 Clear I clean rig floor 03:00 - 03:30 0.50 CASE P PROD2 RU liner runnning tools 03:30 - 04:30 1.00 CASE P PROD2 PU I Run Baker LEM assembly 04:30 - 07:30 3.00 CASE P PROD2 RIH with LEM on 4" DP, to 5297' 07:30 - 12:00 4.50 CASE P PROD2 Establish circ 23 spm, 400 psi, latch LEM into hook wall hanger anchor @ 5305, PIU 10K over to insure latch, drop packer setting ball, pressure up to 3K to set ZXP packer, Bleed off, test annulus to 1.5K to verify packer set, with annulus open pressure DP to 4K to release tool, P/U 15K over tool not released, repeat release procedure, did not release, pressure to 5K didn't release, P/U 30K over tool not released, tryed alternative release method, put left hand turn, slacked off 20K, P/U 30K over, didn't release, put more turns to left 3 turns at a time, slacked off 65K than PIU to 35K over, repeat till had a Printed: 5/31/2005 8:03: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-32 MPE-32 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/4/2005 Rig Release: 5/26/2005 Rig Number: Spud Date: 5/7/2005 End: 5124/2005 07:30 - 12:00 4.50 CASE P PROD2 total of 18 turns to left in pipe, still would not release, Turn back to right only took 9 truns to torq up pipe, picked up 70K over and running tool came free P/U 115K S/O 105K top of LEM 5295', Top of Tie back 5258.55' 12:00 - 13:00 1.00 RUNCOMP RUNCMP PJSM, Displacing OBM wI Brine, Prepare pits fl displacement 13:00 - 14:00 1.00 RUNCOMP RUNCMP Displace OBM with 20 bbls LVT-200, 25 bbls High vis brine@ 9.1, 25 bbls brine with 1.5 bbls Safe Surf-O, 25 bbls brine @ 9,1, 200 bbls sea water @ 8.6, 200 bbls brine @ 9,1 14:00 - 15:30 1.50 RUNCOMP RUNCMP PJSM, clean surface Eqp., flush kill lines, choke and bleeder lines, clean pit #4 for brine. 15:30 - 19:30 4.00 RUNCOMP RUNCMP PJSM, Poh to 5105, standing in derrick, laying down excess pipe, and running tool 19:30 - 21:00 1.50 RUNCOMP RUNCMP PJSM, RIH with DC and HWDP, and drill pipe from offside of derrick to 3105' 21 :00 - 22:30 1.50 RUNCOMP RUNCMP PJSM, POH standing back 4" drill pipe in derrick, laying down HWDP and DC 22:30 - 23:30 1.00 RUNCOMP RUNCMP PJSM, pull wear ring, rig up to test BOPS 23:30 - 00:00 0.50 RUNCOMP RUNCMP Testing BOPS and manifold to 250-3500 psi for 5 min. pertest; Hydril 250-2500 psi for 5 min. per test, the right to witness test was wavier by Chuck Scheave AOOGC, Test was witness by WSL 5/25/2005 00:00 - 10:00 10,00 RUNCm,,p RUNCMP PJSM, Testing BOPS and manifold to 250-3500 psi for 5 min. per test, Hydril 250-2500 psi for 5 min. per test, the right to witness test was wavier by Chuck Scheave AOOGC, Test was witness by WSL, chasing leaks, Kill line valves both leaked HCR and manual, worked and service retested, # 3 and # 2 valve on manifold leaked, repair #2 and 3 valves and retest, pull test plug 10:00 - 11 :00 1.00 RUNCOMP RUNCMP PJSM, rig up to run ESP pump and control line 11 :00 - 14:30 3.50 RUNCOMP RUNCMP PJSM, Picking up ESP pump, Control line 14:30 - 22:30 8.00 RUNCOMP RUNCMP PJSM, Picking up 2 7/8 6.5# L-80 tubing and FMC hanger, total jts run 155 jts, pump @ 5064, XN nipple 4971', GLM 4818', GLM 2017', GLM 147', total LaSalle clamps run 87, P/U 82K, Slo 76K, Block wt 50K 22:30 - 23:30 1.00 RUNCOMP RUNCMP Land tubing, Test TWC to 1000 psi, lay down landing jt. 23:30 - 23:59 0.48 RUNCOMP RUNCMP PJSM, Nipple down BOPS 23:59 - 00:00 0,02 RUNCOI'vT\I MISC RUNCMP For DIMS Score 5/26/2005 00:00 - 01 :30 1.50 RUNCOMP RUNCMP PJSM, Nipple down BOPS 01 :30 - 03:00 1.50 RUNCOMP RUNCMP PJSM, Nipple up FMC 11" X 2 9/16 ESP tubing head adapter and CIW 2 9/16 5k Tree, test tree and packoff to 5000 psi 03:00 - 03:30 0.50 RUNCOMP RUNCMP Pull TWC and install BPV 03:30 - 04:00 0.50 RUNCOMP RUNCMP Secure well, suck out cellar, make final check ESP conductivity test, rig release for rig move @ 04:00 5/26/2005 2 7/8 is not freeze protected will be done by MP after rig move Printed: 5/31/2005 8:03:16 AM WELL SERVICE REPORT WELL MPE-32 DATE 5/26/2005 AFE MSD337440 . UNIT. LRS 64 DAY SUPV HULME NIGHT SUPV UNKNOWN TTL SIZE 0" JOB SCOPE RWO EXPENSE DAILY WORK FREEZE PROT KEY PERSON LRS-SCHREIBER MINID 0" DEPTH OFT DAILY SUMMARY (Post RWO FP) T/IIO=OIOIO. Freeze protect IA wI 65 bbls crude & tbg w/15 bbls crude. FWP=6001010. Init-> 0 0 0 TIME BPIIt! BBLs FLUID TEMP TBG IA OA COMMENTS 06:00 Start ticket. 06:35 Load crude. 07:03 Load diesel . - 07:11 Arrive location. MIRU. 07:38 _ PT to 3000 psi. 07:44 1.3 start crude 100 350 Down IA. 07:55 1.3 15 1100 08:06 1.3 30 1100 08:18 1.3 45 1100 08:33 1.3 65 1100 08:34 RD off IA. RU to tbg. 08:48 P~ to 3500 psi. 08:50 start crude 100 1400 Down tbg. 09:06 15 1600 Shutdown. 09:08 Start RD. 11:29 End ticket. : -- ~,..~'~.< ~~~--,~,..'.,=----,-.~ ...___~, ~__.~_~_A,~_"_ .-~ ~._~__A_..'" Final-> 600 0 0 I FLUID SUMMARY 80 bbls crude SERVICE COMPANY - SERVICE LITTLE RED DAILY COST CUMULTOTAL $1,293 $1,293 $1,293 $1,293 TOTAL FIELD ESTIMATE: Legal Name: Common Name: 5/10/2005 5/15/2005 FIT FIT MPE-32 MPE-32 2,746.0 (ft) 6,299.0 (ft) 2,661.0 (ft) 4,386.0 (ft) 9.00 (ppg) 9.00 (ppg) 280 (psi) 684 (psi) 1,524 (psi) 2,735 (psi) 11.03 (ppg) 12.00 (ppg) . . Printed: 5/31/2005 8:03:09 AM . . Survey Ref: svy1527 Halliburton Sperry-Sun Milne Point Unit BPXA MPE..32 Job No. AKZZ3696012, Surveyed: 17 May, 2005 S u r v e y R e p 0 r t 16 June, 2005 Your Ref: API 500292326100 Surface Coordinates: 6016520.62 N, 569110.40E(70° 27'19.7837" N, 149026'09.6134" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 56.04ft above Mean Sea Level ·r-..........y-·Ul! a R I, L- "'ING - $ E.; Ffv u:: e 5 A H.mbllrton Company ":.1. Halliburton Sperry-Sun Survey Report for MPE-32 Your Ref: API 500292326100 Job No. AKZZ3696012, Surveyed: 17 May, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6520.80 93.080 96.870 4311.35 4367.39 78.57 N 3271.16 E 6016629.53 N 572380.69 E 3269.54 Tie On Point ,,' 6561.00 91.280 98.980 4309.82 4365.86 73.03 N 3310.94 E 6016624.36 N 572420.52 E 6.896 3309.41 Window Point ¡,,(\~ 6566.30 90.990 98.610 4309.72 4365.76 72.22 N 3316.18 E 6016623.60 N 572425.77 E 8.869 3314.66 ~~y 6615,04 87,040 101,910 4310.56 4366.60 63.54 N 3364.12 E 6016615.37 N 572473,78 E 10.559 3362.72 6662.66 88.210 102.790 4312.53 4368.57 53.37 N 3410.59E 6016605.62 N 572520.35 E 3.073 3409.35 "2¡\~ 6699.03 87.590 102.140 4313.86 4369.90 45.52 N 3446.08 E 6016598.11 N 572555.91 E 2.469 3444.96 . 6758.74 93.960 101.830 4313.05 4369.09 33.13 N 3504.45E 6016586.26 N 572614.40 E 10.681 3503.52 6804.74 90.740 100.920 4311.17 4367.21 24.07 N 3549.51E 6016577.61 N 572659.53 E 7.274 3548.71 6854.32 87.160 100.350 4312.08 4368.12 14.92 N 3598.22 E 6016568.92 N 572708.33 E 7.312 3597.55 6904.08 86.180 100.470 4314.97 4371.01 5.95 N 3647.08 E 6016560.40 N 572757.26 E 1.984 3646.54 6950.63 87.590 99.720 4317.50 4373.54 2.208 3692.84 E 6016552.67 N 572803.10 E 3.430 3692.43 7000.76 90.000 99.370 4318.55 4374.59 10.51 8 3742.26 E 6016544.82 N 572852.59 E 4.858 3741.97 7046.67 89.750 99.790 4318.65 4374.69 18,158 3787.53 E 6016537.60 N 572897.93 E 1.065 3787.35 7096.98 89.510 99.570 4318.98 4375.02 26.61 8 3837.12 E 6016529.60 N 572947.60 E 0.647 3837.07 7142.74 89.630 98.900 4319.32 4375.36 33.958 3882.29 E 6016522.68 N 572992.83 E 1.487 3882.34 7187.40 90.250 98.370 4319.37 4375.41 40.66 8 3926.44 E 6016516.38 N 573037.05 E 1.826 3926.60 7239.68 89.260 97.920 4319.59 4375,63 48.07 8 3978.19E 6016509.46 N 573088.87 E 2.080 3978.46 7290.19 91.110 97.900 4319.43 4375.47 55.02 8 4028.22E 6016502.97 N 573138.95 E 3.663 4028.59 7335.70 91.730 97.020 4318.30 4374.34 60.92 8 4073.33 E 6016497.48 N 573184.12 E 2.365 4073.78 7380.84 91.300 96.650 4317.11 4373.15 66.29 8 4118.13 E 6016492.53 N 573228.97 E 1.257 4118.66 7431.81 90.680 96.680 4316.22 4372,26 72.21 8 4168.75E 6016487.08 N 573279.64 E 1.218 4169.37 7480.22 91.920 96.090 4315.13 4371.17 77.598 4216.85 E 6016482.15 N 573327.78 E 2.836 4217.54 . 7527.67 90.990 94.920 4313.92 4369.96 82.14 8 4264.06 E 6016478.04 N 573375.04 E 3.149 4264.82 7578.88 89.630 93.970 4313.64 4369.68 86.11 S 4315.11 E 6016474.54 N 573426.13 E 3.239 4315.93 7624.11 88.030 92.770 4314.57 4370.61 88.778 4360.25 E 6016472.30 N 573471.29 E 4.421 4361.11 7667.69 89.570 92.930 4315.48 4371.52 90.94 8 4403.77 E 6016470.54 N 573514.82 E 3.553 4404.65 7719.22 89.130 92.510 4316.06 4372.10 93.38 8 4455.24 E 6016468.57 N 573566.31 E 1.180 4456.15 7769.01 89.880 91.510 4316.50 4372.54 95.13 8 4504.99E 6016467.29 N 573616.08 E 2.510 4505.93 7816.40 90.490 92.030 4316.34 4372.38 96.59 8 4552.36 E 6016466.26 N 573663.46 E 1.691 4553.31 7865.47 91.110 89.450 4315.66 4371.70 97.228 4601,,42 E 6016466.08 N 573712.52 E 5.407 4602.37 7912.72 91.540 89.720 4314.56 4370.60 96.88 8 4648.65 E 6016466.86 N 573759.75 E 1.075 4649.60 7958.04 91.050 88.890 4313.54 4369.58 96.33 8 4693.96 E 6016467,83 N 573805.05 E 2.126 4694.89 8008.65 90.680 88.090 4312.78 4368.82 95.00 8 4744.54 E 6016469.64 N 573855.62 E 1.741 4745.45 8053.35 90.370 88.490 4312.37 4368.41 93,66 8 4789.22 E 6016471.39 N 573900.28 E 1.132 4790.10 8104.38 89.880 87.840 4312.26 4368.30 92.03 8 4840.42 E 6016473.49 N 573951.27 E 1.595 4841.07 16 June, 2005 - 14:33 Page 2 of.4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report/or MPE-32 Your Ref: API 500292326100 Job No. AKZZ3696012, Surveyed: 17 May, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/10Oft) 8153.74 89.750 87.740 4312.41 4368.45 90.13S 4889.55 E 6016475.85 N 574000.57 E 0.332 4890.36 8200.46 94.950 86.670 4310.50 4366.54 87.85 S 4936.16 E 6016478.56 N 574047.16 E 11.363 4936.93 8249.99 94.440 86.290 4306.45 4362.49 84.82 S 4985.43 E 6016482.05 N 574096.40 E 1.283 4986.14 8296.83 95.250 88.120 4302.49 4358.53 82.55 S 5032,04 E 6016484,76 N 574142,99 E 4.260 5032.72 8346.35 90.000 88.310 4300.22 4356.26 81.01 S 5081.47E 6016486.76 N 574192.40 E 10.609 5082.11 8392.99 89.140 89.510 4300.57 4356.61 80.12 S 5128.10E 6016488.08 N 574239.02 E 3.165 5128.72 . 8442.80 89.510 89.540 4301.16 4357.20 79.71 S 5177.90 E 6016488.95 N 574288.82 E 0.745 5178.52 8489.27 89.690 89.650 4301.48 4357.52 79.38 S 5224.37 E 6016489.71 N 574335.28 E 0.454 5224.97 8539.80 89.810 90.330 4301.70 4357.74 79.37 S 5274.90 E 6016490.19 N 574385.81 E 1.367 5275.50 8585.39 90.370 90.100 4301.63 4357.67 79.54 S 5320.49 E 6016490.44 N 574431.40 E 1.328 5321.08 8635.40 91.170 89.690 4300.96 4357.00 79.45 S 5370.49 E 6016490.99 N 574481.40 E 1.797 5371.08 8681.50 87.470 88.010 4301.51 4357.55 78.52 S 5416.57E 6016492.35 N 574527.47 E 8.814 5417.14 8727.93 86.100 88.930 4304.11 4360.15 77.28 S 5462.91 E 6016494.01 N 574573.79 E 3.552 5463.45 8775.75 89.070 88.320 4306.13 4362.17 76.14 S 5510.67 E 6016495.60 N 574621.54 E 6.340 5511.19 8824.04 91.730 87.420 4305.79 4361.83 74.34 S 5558.92 E 6016497.85 N 574669.77 E 5.815 5559.40 - 8894.00 91.730 87.420 4303.68 4359.72 71.20 S 5628.78 E 6016501.64 N 574739.59 E 0.000 5629.20 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 90.890° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8894.00ft., The Bottom Hole Displacement is 5629.23ft., in the Direction of 90.725° (True). . 16 June, 2005 - 14:33 Page 3 of4 DrillQuest 3.03.06.008 Milne Point Unit Comments Measured Depth (ft) 6520.80 6561.00 8894.00 Halliburton Sperry-Sun Survey Report for MPE-32 Your Ref: AP/500292326100 Job No. AKZZ3696012, Surveyed: 17 May, 2005 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4367.39 4365.86 4359.72 Comment 78.57 N 73.03 N 71.20 S 3271.16 E 3310.94 E 5628.78 E Tie On Point Window Point Projected Survey . Survey tool proøram for MPE-32 From Measured Vertical Depth Depth (ft) (ft) 0.00 469.00 16 June, 2005·14:33 0.00 468.92 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 469.00 8894.00 468.92 AK-1 BP _HG - WellNav Gyro (MPE-32PB1) 4359.72 MWD+IIFR+MS+SAG (MPE-32PB1) . Page 4 of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Milne Point Unit BPXA MPE-32PB1 . Job No. AKZZ3696012, Surveyed: 16 May, 2005 Survey Report 16 June, 2005 Your Ref: API 500292326170 Surface Coordinates: 6016520.62 N, 569110.40 E (70027'19.7837" N, 149026' 09.6134" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 56.04ft above Mean Sea Level . 5""'1:::1 ·.....y....SUi..., DRIL.L.'ING SERVlce!'!S A Halliburton Company Survey Ref: svy1519 Halliburton Sperry-Sun Survey Report for MPE-32PB1 Your Ref: AP/500292326170 Job No. AKZZ3696012, Surveyed: 16 May, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 0.00 0.000 0.000 -56.04 0.00 0.00 N 0.00 E 6016520.62 N 569110.40 E 0.00 AK-1 BP _HG - WellNav Gyro 91.00 0.420 276.000 34.96 91.00 0.03 N 0.33W 6016520.65 N 569110.07 E 0.462 -0.33 183.00 0.430 268.000 126.96 183.00 0.06 N 1.01 W 6016520.67 N 569109.39 E 0.065 -1.01 274.00 0.610 274.700 217.95 273.99 0.09 N 1.84W 6016520.69 N 569108.56 E 0.208 -1.84 363.00 0.650 354.570 306.95 362.99 0.63 N 2.36W 6016521.23 N 569108.04 E 0.909 -2.37 469.00 3.340 38.540 412.88 468.92 3.64 N 0.49W 6016524.26 N 569109.88 E 2.743 -0.55 MWD+IIFR+MS+SAG . 561.68 3.890 39.850 505.37 561.4 1 8.17 N 3.21 E 6016528.82 N 569113.53 E 0.600 3.08 651.95 3.780 51.690 595.44 651.48 12.36 N 7.50E 6016533.05 N 569117.79 E 0.884 7.31 749.31 3.910 60.550 692.58 748.62 15.98 N 12.91 E 6016536.72 N 569123.16 E 0.624 12.66 842.48 5.480 65.320 785.44 841.48 19.40 N 19.72E 6016540.21 N 569129.94 E 1.735 19.42 942.10 7.170 72.300 884.45 940.49 23.28 N 29.97 E 6016544.18 N 569140.15 E 1.861 29.60 1038.98 9.140 70.230 980.35 1036.39 27.72 N 42.97 E 6016548.74 N 569153.11 E 2.056 42.53 1133.59 11.590 73.850 1073.41 1129.45 32.91 N 59.17 E 6016554.08 N 569169.27 E 2.678 58.66 1229.29 13.290 73.970 1166.86 1222.90 38.62 N 78.98 E 6016559.97 N 569189.02 E 1.777 78.37 1325.59 14.300 68.690 1260.38 1316.42 46.00 N 100.70 E 6016567.55 N 569210.67 E 1.675 99.97 1420.45 16.530 67.940 1351.82 1407.86 55.33 N 124.12 E 6016577.09 N 569234.01 E 2.360 123.25 1516.65 17.650 64.670 1443.78 1499.82 66.71 N 149.99 E 6016588.71 N 569259.77 E 1.534 148.94 1613.15 17.900 64.070 1535.67 1591.71 79.45 N 176.55 E 6016601.70 N 569286.21 E 0.321 175.30 1708.80 17.110 63.750 1626.89 1682.93 92.10 N 202.39 E 6016614.59 N 569311.93 E 0.832 200.94 1805.33 17.810 66.520 1718.97 1775.01 104.26 N 228.67 E 6016627.00 N 569338.09 E 1.125 227.02 1902.01 18.220 67.160 1810.91 1866.95 116.02 N 256.1§E 6016639.01 N 569365.47 E 0.471 254.32 1996.72 18.060 67,820 1900.92 1956.96 127.31 N 283.40E 6016650.55 N 569392.60 E 0.275 281.39 . 2092.81 18.900 66.310 1992.05 2048.09 139.19 N 311.44E 6016662.69 N 569420.54 E 1.006 309.24 2188.86 18.800 65.950 2082.95 2138.99 151.74 N 339.82 E 6016675.51 N 569448.80 E 0.160 337.42 2285.57 18.660 65.270 2174.54 2230.58 164.57 N 368.10 E 6016688.59 N 569476.96 E 0.268 365.50 2382.11 20.850 63.230 2265.39 2321.43 178.77 N 397.47 E 6016703.07 N 569506.20 E 2.378 394.65 2478,30 21.110 62.040 2355.20 2411.24 194.60 N 428.06 E 6016719.18 N 569536.63 E 0.519 424.98 2573.35 21,360 61.340 2443,80 2499.84 210.93 N 458.36 E 6016735.79 N 569566.79 E 0.375 455.03 2669.44 21 .280 61 .880 2533.32 2589.36 227.54 N 489.10 E 6016752.69 N 569597.37 E 0.221 485.51 2688.54 21.250 62.130 2551.12 2607.16 230.79 N 495.22 E 6016755.99 N 569603.45 E 0.500 491.57 2761.72 20.720 62.010 2619.44 2675.48 243.06 N 518.37 E 6016768.48 N 569626.49 E 0.727 514.53 2854.18 20.810 61.740 2705.90 2761.94 258.52 N 547.28 E 6016784.20 N 569655.26 E 0.142 543.20 2948.67 20.310 61.140 2794.37 2850.41 274.38 N 576.43E 6016800.33 N 569684.26 E 0.574 572.09 3043.34 20.050 65.150 2883.23 2939.27 289.13 N 605.54E 6016815.36 N 569713.23 E 1.487 600.98 3139.56 20.180 64.990 2973.58 3029.62 303.08 N 635.55 E 6016829.58 N 569743.11 E 0.147 630.77 16 June, 2005 - 14:32 Page 2 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPE-32PB1 Your Ref: AP/500292326170 Job No. AKZZ3696012, Surveyed: 16 May, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3235.77 20.160 64.440 3063.89 3119.93 317.25 N 665.55 E 6016844,03 N 569772.97 E 0.198 660.54 3332.35 19.850 64.080 3154.64 3210.68 331.60 N 695.31 E 6016858.65 N 569802.60 E 0.345 690.07 3426.76 22.170 65.200 3242.77 3298.81 346.08 N 725.90 E 6016873.41 N 569833.06 E 2.494 720.44 3521.48 24.250 70.660 3329.83 3385.87 360.02 N 760.48 E 6016887.68 N 569867.51 E 3.158 754.80 3617.68 25.730 74.650 3417.03 3473.07 372.09 N 799.27 E 6016900.11 N 569906.18 E 2.331 793.39 3713.82 27.350 81.830 3503.06 3559.10 380.75 N 841.26E 6016909.16 N 569948.10 E 3.735 835.25 . 3809.94 30.420 88.230 3587.23 3643,27 384.65 N 887.47 E 6016913.48 N 569994.26 E 4.529 881.38 3904.41 33.560 92.080 3667.35 3723.39 384.44 N 937.48 E 6016913.74 N 570044.28 E 3.962 931 .40 4000.88 37.340 96.840 3745.94 3801.98 379.98 N 993.21 E 6016909.80 N 570100.04 E 4.850 987.19 4095.82 39.720 97.300 3820.20 3876.24 372.70 N 1051.90 E 6016903.06 N 570158.79 E 2.525 1045.98 4191.96 41.690 97.120 3893.08 3949.12 364.83 N 1114.10 E 6016895.77 N 570221.06 E 2.053 1108.29 4288.18 44.630 97.860 3963.26 4019.30 356.24 N 1179.34E 6016887.79 N 570286.39 E 3.100 1173.67 4383.58 49.000 98.660 4028.53 4084.57 346.23 N 1248.16 E 6016878.42 N 570355.30 E 4.621 1242.63 4480.14 54.130 99.340 4088.54 4144.58 334.39 N 1322.84 E 6016867.27 N 570430.08 E 5.341 1317.49 4574.53 58.510 99.700 4140.87 4196.91 321.39 N 1400.28 E 6016854.99 N 570507.64 E 4.651 1395.12 4671 .06 63.500 98.200 4187.65 4243.69 308.29 N 1483.66 E 6016842.66 N 570591.14 E 5.345 1478.69 4767.10 69.100 98.680 4226.24 4282.28 295.38 N 1570.61 E 6016830.56 N 570678.21 E 5.849 1565.84 4863.25 68.860 97.330 4260.73 4316.77 282.88 N 1659.49 E 6016818.88 N 570767.19 E 1.334 1654.89 4958.89 68.310 97.750 4295.65 4351.69 271 .20 N 1747.75 E 6016808.02 N 570855.56 E 0.706 1743.33 5055.36 68.380 98.290 4331.25 4387.29 258.69 N 1836.54 E 6016796.33 N 570944.46 E 0.525 1832.30 5151.59 74.560 99.220 4361.81 4417.85 244.80 N 1926.67 E 6016783.28 N 571034.72 E 6.487 1922.63 5201.38 79.890 98.700 4372.82 4428.86 237.24 N 1974.62 E 6016776.16 N 571082.73 E 10.753 1970.69 . 5248.46 80.270 98.650 4380.93 4436.97 230.24 N 2020.46 E 6016769.60 N 571128.64 E 0.814 2016.64 5296.48 79.770 97.540 4389.25 4445.29 223.58 N 2067.28 E 6016763.37 N 571175.52 E 2.503 2063.56 5344.75 78.390 97.460 4398.40 4454.44 217.40 N 2114.27 E 6016757.62 N 571222.57 E 2.864 2110.64 5394.41 81.500 98.850 4407,07 4463.11 210.46 N 2162.67 E 6016751.13 N 571271.02 E 6.842 2159.14 5441 .09 83.510 99.120 4413.15 4469.19 203.23 N 2208.38 E 6016744.33 N 571316.80 E 4.344 2204.96 5491.66 87.660 99.500 4417.05 4473.09 195.08 N 2258.12 E 6016736.63 N 571366.62 E 8.241 2254.82 5537.61 89.510 99.650 4418.18 4474.22 187.43 N 2303.42 E 6016729.41 N 571411.98E 4.039 2300.23 5586.48 92.400 97.340 4417.37 4473.41 180.22 N 2351.74 E 6016722.65 N 571460.36 E 7.570 2348.65 5631.91 89.990 95.500 4416.42 4472.46 175.14 N 2396.87 E 6016717.99 N 571505.54 E 6.674 2393.86 5680.89 91 .200 96.970 4415.91 4471.95 169.82 N 2445.55 E 6016713.12 N 571554.27 E 3.887 2442.62 5728.73 94.240 96.970 4413.64 4469.68 164.02 N 2492.98 E 6016707.76 N 571601.75 E 6.355 2490.13 5776.49 97.920 96.740 4408.58 4464.62 158.35 N 2540.12 E 6016702.53 N 571648.94 E 7.720 2537.36 5823.78 101.430 97.100 4400.64 4456.68 152.74 N 2586.39 E 6016697.35 N 571695.27 E 7.460 2583.71 16 June, 2005 - 14:32 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPE-32PB1 Your Ref: AP/500292326170 Job No. AKZZ3696012, Surveyed: 16 May, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 5872.81 105.550 96.670 4389.20 4445.24 147.02 N 2633.72 E 6016692.07 N 571742.64 E 8.446 2631.12 5919.92 105.430 96.070 4376.62 4432.66 141.99 N 2678.83 E 6016687.45 N 571787.80 E 1.254 2676.31 5966.97 105.080 94.950 4364.24 4420.28 137.63 N 2724.02 E 6016683.51 N 571833.02 E 2.414 2721.55 6014.39 101.950 94.810 4353.16 4409.20 133.71 N 2769.95 E 6016680.02 N 571878.99 E 6.607 2767.54 6063.33 98,030 96.850 4344.67 4400.71 128.81 N 2817.89 E 6016675.56 N 571926.97 E 9.000 2815.55 6110.90 95.890 95.820 4338.90 4394.94 123.60 N 2864.81 E 6016670.79 N 571973.94 E 4.986 2862.55 . 6163.99 93.870 97.220 4334.39 4390.43 117.59 N 2917.37 E 6016665.27 N 572026.55 E 4.624 2915.19 6206.65 91.920 96.760 4332.23 4388.27 112.41 N 2959.65 E 6016660.48 N 572068.88 E 4.696 2957.55 6246.09 91.180 96.360 4331.17 4387.21 107.90 N 2998,82 E 6016656.34 N 572108.09 E 2.133 2996.78 6277.51 91.980 96.260 4330.30 4386.34 104.45 N 3030.04 E 6016653.17 N 572139.34 E 2.566 3028.05 6374.25 95.260 95.940 4324.19 4380.23 94.19 N 3126.02 E 6016643,81 N 572235.42 E 3.407 3124.18 6420.30 95.570 96.000 4319.85 4375.89 89.42 N 3171.62 E 6016639.46 N 572281.05 E 0.686 3169.85 6470.36 95.380 96,010 4315.07 4371.11 84.21 N 3221.18 E 6016634.71 N 572330.66 E 0.380 3219.48 6520.80 93.080 96.870 4311.35 4367.39 78.57 N 3271.16 E 6016629.53 N 572380.69 E 4.867 3269.54 " 6566.20 91 .050 99.250 4309.72 4365.76 72.21 N 3316.08 E 6016623.59 N 572425.66 E 6.887 3314.55 p~r 6609.17 89.320 101.470 4309.58 4365.62 64.48 N 3358.34 E 6016616.25 N 572468.00 E 6.550 3356.93 6661.47 89.260 101.640 4310.22 4366.26 54.01 N 3409.58 E 6016606.25 N 572519.33 E 0.345 3408.33 6713.41 90.800 102.960 4310.20 4366.24 42.94 N 3460.32 E 6016595.66 N 572570.17 E 3.905 3459.24 Æ~ 6758.63 92.220 101 .890 4309.01 4365.05 33.22 N 3504.47 E 6016586.34 N 572614.41 E 3.931 3503.53 6806.64 93.450 102.020 4306.63 4362.67 23.28 N 3551.38 E 6016576.85 N 572661.41 E 2.576 3550.59 6854.17 91.790 101.880 4304.46 4360.50 13.45 N 3597.83 E 6016567.45 N 572707.95 E 3.505 3597.18 6905.12 87.650 101 .530 4304.71 4360.75 3.12 N 3647.70E 6016557.58 N 572757.92 E 8.155 3647.22 . 6950.35 87.160 101.590 4306.76 4362.80 5.94 S 3691.97 E 6016548.93 N 572802.27 E 1.091 3691.62 6999.61 87.090 101.620 4309.23 4365.27 15.83 8 3740.16 E 6016539.48 N 572850.55 E 0.155 3739.96 7046.12 86.910 101.760 4311.66 4367.70 25.24 8 3785.65 E 6016530.49 N 572896.12 E 0.490 3785.58 7094.18 86.970 101 .330 4314.23 4370.27 34.85 8 3832.67 E 6016521.33 N 572943.23 E 0.902 3832.75 7142.30 86.600 101 .240 4316.92 4372.96 44.25 8 3879.78 E 6016512.36 N 572990.43 E 0.791 3880.00 7193.79 86.230 101.510 4320.14 4376.18 54.39 S 3930.16 E 6016502.69 N 573040,90 E 0,889 3930.53 7239.83 87.220 98.250 4322.78 4378.82 62.278 3975.44 E 6016495.23 N 573086.25 E 7.389 3975.93 7286.67 87.210 97.020 4325.05 4381.09 68.49 8 4021.81 E 6016489.44 N 573132.67 E 2.623 4022.39 7331.05 85.130 95.220 4328.02 4384.06 73.21 8 4065.83 E 6016485.13 N 573176.74 E 6.192 4066.48 7383.07 85.170 93.590 4332.41 4388.45 77.198 4117.51 E 6016481.63 N 573228.45 E 3.123 4118.21 7431.70 86.120 90.200 4336.11 4392.15 78.79 S 4165.97 E 6016480.48 N 573276.92 E 7.220 4166.69 7477.38 85.740 89.610 4339.35 4395.39 78.728 4211.53 E 6016480.98 N 573322.48 E 1.534 4212.25 7528.22 89.750 91.210 4341.35 4397.39 79.08 8 4262.32 E 6016481.08 N 573373.27 E 8.491 4263.03 16 June, 2005 - 14:32 Page 40f 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPE-32PB1 Your Ref: AP/500292326170 Job No. AKZZ3696012, Surveyed: 16 May, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastin9s Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7572.95 92.590 91.400 4340.44 4396.48 80.10 S 4307.02 E 6016480.48 N 573417.98 E 6.363 4307.75 7624.55 93.900 90.310 4337.52 4393.56 80.87 S 4358.53 E 6016480.19 N 573469.49 E 3.300 4359.26 7670.24 93.640 89.230 4334.51 4390.55 80.68 S 4404.12 E 6016480.79 N 573515.08 E 2.426 4404.84 7721.21 97.160 90.070 4329.72 4385.76 80.37 S 4454.86 E 6016481.58 N 573565.81 E 7.098 4455.57 7770.71 97.100 88.600 4323.57 4379.61 79.80 S 4503.97 E 6016482.60 N 573614.92 E 2.949 4504.67 7816.56 99.180 87.870 4317.08 4373.12 78.41 S 4549.33 E 6016484.42 N 573660.26 E 4.802 4550.00 . 7867.62 98.820 88.170 4309.09 4365.13 76.66 S 4599.73 E 6016486.63 N 573710.65 E 0.913 4600.37 7912.86 98.500 87.370 4302.28 4358.32 74.92 S 4644.42 E 6016488.78 N 573755.32 E 1.886 4645.03 7956.77 98.050 87.250 4295.96 4352.00 72.88 S 4687.83 E 6016491.23 N 573798.70 E 1.060 4688.40 8045.00 98.050 87.250 4283.61 4339.65 68.69 S 4775.09 E 6016496,23 N 573885.92 E 0.000 4775.58 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 90.890° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8045.00ft., The Bottom Hole Displacement is 4775. 58ft. , in the Direction of 90.824° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 8045.00 4339.65 68.69 S 4775.09 E Projected Survey 16 June, 2005 - 14:32 Page 5 of 6 DrillQuest 3.03.06.008 Milne Point Unit Halliburton Sperry-Sun Survey Report for MPE-32PB1 Your Ref: AP/500292326170 Job No. AKZZ3696012, Surveyed: 16 May, 2005 BPXA Survey tool program for MPE-32PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 469.00 0.00 468.92 16 June, 2005 - 14:32 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 469.00 8045.00 . 468.92 AK-1 BP _HG - WellNav Gyro 4339.65 MWD+IIFR+MS+SAG . Page 6 of 6 DrillQuest 3.03.06.008 . . WELL LOG TRANSMITI AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 27, 2005 RE: MWD Formation Evaluation Logs MPE-32, AK-MW-3696012 1 LIS formatted Disc with verification listing. tt' /1 ), / À API#: 50-029-23261-00 ¡ PLEASE ACKNOWLEDGE RECEIPf BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: J.J¡J' Jti. C' Signed: ,,4/ j' L /,- ¡ t , J' t. ~ : (j '1-1 :< ü ç - D \ S- k (, . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite toO Anchorage, Alaska 99501 June 27, 2005 RE: MWD Fonnation Evaluation Logs MPE-32 PB1, AK-MW-3696012 1 LIS formatted Disc with verification listing. # {J Á t ~ API#: 50-029-23261-70 PLEASE ACKNOWLEDGE RECEIYf BY SIGNING A COpy OF THE TRANSMITTAL LEITER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: J.- ~t'ÀJ\'t \- 'jU. ô/L-J Signed: À (; S' - ~ ~ r (=<It. \ .... ~ . . Subject: Re: Diverter Variance Milne Point Well MPE-32 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 03 May 2005 15:17:55 -0800 To: "Johnson, David A. (Fairweather)" <john23@BP.com> CC: Fred Johnson <JohnsoFC@BP.com> dQ;-OCoS- David, What you propose for MPE-32 is similar to what you have developed for earlier wells on E pad. Having an established plan in place to depressurize/deenergize the equipment that could be affected should a divert event be necessary is an important mitigation step. I do appreciate the work you all have done to address this matter. When grass roots drilling is planned on other pads with similar cramped geometries, applicable SD plans should also be developed. With the mitigation plan in place, you proposal to shorten the diverter line to -50' is accepted. Please make sure that a copy of the plan and this message is available at the rig. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, We would like to request a variance for the diverter line length on MPE-32 location from 75' to 50'. The header layout on the E-Pad does not allow room to run the required 75' length diverter line as there is not sufficient clearance to run the diverter line thru the header. This will require a shorter diverter length of 50' and the end of the diverter will be approximately 15' from the header. A variance is requested for the shorter diverter line length. A notification procedure will be posted on the rig for an emergency shut down of E-pad in the event it is necessary to divert the well. See attached procedure. This is the second of four wells planned on E-pad. A variance has been approved for MPE-28. The permit application for MPE-12 (permit pending approval) includes the request for the variance to the diverter length. The permit for MPE-31will be submitted next week. This well will also need a variance in the diverter line length. Thank you Dave Johnson «E-pad shut-in.doc» 1 of 1 5/3/20053:18 PM . . . . Doyon 14 contingency plan in the event of using Divert line E-Pad · Doyon 14 rig will have a Mine Point radio and will have met with E-Pad operator(s) and infonned them of the placement of their Divert Line, who in turn will infonn ALL personnel who will be doing work on the pad. Nabors 4ES, contractors etc. · This Divert Line will have to be run under LIVE lines. Production, Test and Injection, due to space constraints on the pad. · In the event of using Divert Line, Doyon rig will call Milne Point control room board operator and request an ESD of E- Pad. · Doyon rig will then call Milne Point radio and infonn them of action taken and why. Milne Point radio will make an announcement of restricted access to E-pad. · Control room board operator will notify E and S-Pad operators and then initiate ESD for the pad shutting down production from all wells and all injection as well. The control room operator will also cut off electrical power to the pad. · The control room will then shut in XV-5873A the perimeter gas injection valve for E-Pad. · The control room board operator will shut in water injection for Sand E-Pads with the corresponding perimeter valve XV -5310. To make up for the loss of injection, board operator may have to divert water to B-50 injection well. · Doyon rig will then correspond with E-Pad operator about situation who will then account for all personnel under their authority and direct them to safe area. S-Pad operator will make required adjustments for loss of water injection. · E-Pad operator will then verify pad is in ESD mode and all wells and corresponding equipment did in fact shut in and ALL ESP's shut down. · In the event that Nabors 4ES is also on the pad they will have to be notified of any such action. · Once situation has been rectified Doyon rig will the notify the E-Pad operator, the control room board operator and Milne Point radio so provisions can be made to bring the pad back on line. 97,; ¡,·¡-'ð i.. ~ . . . ~ 1. i., UirU 'f":3 16 ! ¡ Lb . îf.n I.. U.f?".r iU' ¡ F ~.j . AI#ASHA OIL AlÐ) GAS F d J hn CONSERVATION COMMISSION re 0 son Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: MPE 32 BP Exploration (Alaska), Inc. Permit No: 205-065 Surface Location: 3984' NSL, 2032' WEL, Sec. 25, T13N, RIOE, UM Bottomhole Location: 3893' NSL, 1643' WEL, Sec. 30, T13N, RIlE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. PIe e ¡provide at least twenty-four (24) hours notice for a representative of the Commission t w' ! ss any required test. Contact the Commission's petroleum field inspector at (907 59- (ger). DATED this ~ of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. a STATE OF ALASKA A ALASKA ~ AND GAS CONSERVATION COrvWSSION PERMIT TO DRILL 20 MC 25.005 11 b. Current Well Class . , 0 Expl?ratory II Devemwattil~ R, B.~, ."'¥RI,i Z¡oftthmis3Íon o Stratigraphic Test 0 Service 0 Develò'þ'r'I'1'ént~å~ ~~i^'dlt¡"~'oMê' 5. Bond: IBI Blanket 0 Single Well 11. Well Name anêlt4bRf_ Bond No. 2S100302630-277 MPE-32 / 6. Proposed Depth: / 12. Field I Pool(s): MD 8906' / TVD 4382' Milne Point Unit I Schrader Bluff 7. Property Designation: ADL 028231 13. Approximate Spud Date: 05/02/05 14. Distance to Nearest Property: 6950' , 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 57.8' feet 390' away from MPE-06 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1913' Surface: 1467 ' Setting Depth ," qUélptitypf Cørnøot Top . Bottom (cJ.orsacks) MD TVD MD TVD (including stage data) Surface Surface 122' 122' 260 sx Arctic Set (Approx.) Surface Surface 2748' 2657' 418 sx AS Lite, 371 sx Class 'G' Surface Surface 6227' 4357' 725 sx Class 'G' 6227' 4357' 8906' 4383' Screens II Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3984' NSL, 2032' WEL, SEC. 25, T13N, R10E, UM Top of Productive Horizon: 4206' NSL, 5159' WEL, SEC. 30, T13N, R11E, UM Total Depth: 3893' NSL, 1643' WEL, SEC. 30, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569110 / y- 6016521' Zone- ASP4 16. Deviated Wells: Kickoff Depth: 400' / feet Maximum Hole Angle: 105 degrees 8. Land Use Permit: 9. Acres in Property: 2560 18. Casing Program: Size Casing 20" 10-3/4" 7-5/8" Specifications Grade Coupling H-40 Weld L-80 BTC-M L-80 BTC-M L-80 Hole 42" Weight 92# 45.5# 29.7# 15.2# Length 122' 2748' 6227' 2679' 13-112" 9-7/8" 6-3/4" 4" 19. PRESENT WELL CONDITION SUMMARY (To be completed for RedrilfAND Total Depth MD (ft): Total Depth TVD Plugs (measured): Effective Depth MD (ft): Effective Depth TVD I*' RECEIVED C-\btp APR of ~ 2005 Junk (measured): Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): perfOration Depth TVD (ft): IBI Drilling Program 0 Time vs Depth Plot o Seabed Report IBI Drilling Fluid Program 20. Attachments IBI Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Fred Title Senior Drilling Engineer Phone S6 API Number: Q 2 3.., /_(' /v_. 50- D 2:./ - .c..AC- '-Ù es Required 0 Yes gNo en Sulfide Measures 0 Yes ~No Permit APPlqvf-1 .-,) Á Date: '-1 I;). I ó 7 Mud Log Required Directional Survey Required APPROVED BY THE COMMISSION / o Shallow Hazard Analysis 1B120 AAC 25.050 Requirements Date: Contact Walter Quay, 564-4178 Prepared By Name/Number: Sondra Stewman, 564-4750 1 See cover letter for other requirements DYes ;(No ~Yes 0 No Date i1¿ . bp . I Well Name: I MPE-32 I Schrader NC/ND & OA Dual Lateral Horizontal Producer Drilling and Completion Plan Summary I Type of Well: I Schrader Bluff Horizontal Producer Surface Location: (As Proposed) Tl - Top NB Downgoing Side T2 - Top OA on Invert T3 - Base NC/ND on Upgoing Side T4 - Mid NC/ND lateral TS - Mid NC/ND lateral T6 - Mid NC/ND lateral Tl OA Lateral -- Mid-OA T2 OA Lateral -- Mid-OA T3 OA Lateral - Top OA Distance to Property line Distance to nearest well 3,984' FSL and 2,032' FEL Section 25, T13N, R10E UM E = 569,110' N = 6,016,521' 4,274' FSL and 282' FEL Section 25, T13N, R10E UM E = 570,857' N = 6,016,827' Z = 4,343' TVD 4,206' FSL and 5,159' FEL Section 30, T13N, R11 E UM E = 571,220' N = 6,016,762' Z = 4,468' TVD 4,083' FSL and 4,302' FEL Section 30, T13N, R11 E UM E = 572,079' N = 6,016,648' Z = 4,357' TVD 4,020' FSL and 3,852' FEL Section 30, T13N, R11 E UM E = 572,530' N = 6,016,590 Z = 4,353 TVD 3,862' FSL and 2964' FEL Section 30, T13N, R11 E UM E = 573,420' N = 6,016,440' Z = 4,368' TVD 3,893' FSL and 1,643' FEL Section 30, T13N, R11 E UM E = 574,740' N = 6,016,485' Z = 4,383' TVD 4,020' FSL and 3,852' FEL Section 30, T13N, R11E UM E = 572,530' N = 6,016,590' Z = 4,452' TVD 3,862' FSL and 2,964' FEL Section 30, T13N, R11 E UM E = 573,420' N = 6,016,440' Z = 4,463' TVD 3,893' FSL and 1 ,643' FEL Section 30, T13N, R11E UM E = 574,740' N = 6,016,485' Z = 4,473' TVD 6,9S0' 390' from MPE-06 I AFE Number: 1 I Estimated Start Date: 1 02 May OS / I Rig: 1 Doyon 14 Rig days to complete: I 14 MD: I 8,906' ¡ I TVD: 14,382' r 1 Max Inc: 11 OSO Well Design: Slimhole Objective: Schrader Bluff NC/ND & OA 1 I KOP: 1400' I, I KBE:ls7.8' Page . . Mud Program: 13-1/2" Surface .I 8.6-9.8 1 0-30 30-50 8.5-9.5 NC-8 < 1500 v MW to 9.8 ppg, prior to drilling below the PF for Hydrates 8.8 - 9.4 8 - 25 26 - 32 < 1500 9.0-9.5 6-8 < 25 9.0 15 - 24 15 - 21 <8 80:20 550 - 900 ~ 6-3/4" OA Production Hole (5,346' - 8,898'): MOBM (' 9.0 15 - 24 15 - 21 <8 80:20 550 - 900 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. CasingITubing Program Hole Csg Diam WtlFt Grade Conn Burst Collapse Length Top Bottom Size MDI MDI TVDrkb TVDrkb 42-in 20-in* 92 H-40 Weld 1530 520 122-ft 0 122~ft / 122- ft 13.5-in 1O.75-in 45.5 L-80 BTC- 5210 2480 2,748 0 2.748' / M 2,657 9.875-in 7.625-in 29.7 L-80 BTC- 6890 4790 6,227' 0 6,227/ ~ ~- I ,357 ) 6.75-in 4 in Screens 15.2 L-80 2,679 6,227/ 8,906' / NC/ND 4,35l 4,383 6~ 4 Y2" Slotted 12.0' L-80 BTC 3,552 5,346/ 8,898' / OA Liner 4,468 4,472 Cement Program: Casing Size Basis Total Cement Volume: 407 bbl 10-3/4",45.5#, L-80, BTC Surface Casing Tail cement = To PF. 40% Excess over Gauge Hole Lead to surface. 150% Excess over Gauge Hole from PF to Surface 5 bbl water Wash 20 bbl CW 100 Spacer 50 bbl of MudPush Page 2 Casing Size Basis Total Cement Volume: 150 bbl . . Lead 330 bbl, 418 sx of ArcticSet Lite: 10.7 ppg and 4.44 ft3/SX Tail 77 bbl, 371 sx "G" mixed at 15.8 Ib/gal & 1.17 ffl/sx 7-5/8",29.7#, L-80, BTC-M Intermediate Casing Tail cement = 500' MD above the TUZC. 40% Excess over Gauge Hole Wash Spacer Tail Temp 5-bbl water 10 bbl CW 100 20 bbl of MudPush 150 bbl, 725 sx "G" mixed at 15.8 Ib/gal & 1.16 ft;;!/sx BHST ==80°F from SOR Page 3 . Evaluation Program: 13-1/2" Section Open Hole: . · Gyro · MWD/GR/RES · IFR/CASANDRA, · InSite 9-7/8" Section "'" C~ole: 6-3/4" SeCuõn NC/ND Open Hole: 6-3Ì4--section --- OA Open Hole: · MWD/GR/RES · IFR/CASANDRA, · Sperry InSite ---- ----- ~ ----------. --- -------- · MWD/GR/RES (ASI) ( · IFR/CASANDRA, · Sperry InSite ----- · MWD/GR/RES (ASI) · IFR/CASANDRA, · Sperry InSite Cased Hole: Formation Markers: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (Ib/gal) BPRF 1982 1937 816 8.35 Top Ugnu (TUZC) 3995 3798 1624 8.35 Ugnu-MA 4350 4054 1735 8.35 Ugnu-MB1 4366 4064 1739 8.35 Ugnu-MB2 4472 4128 1767 8.35 Ugnu-MC 4794 4282 1834 8.35 SBF2-NA 4865 4309 1846 8.35 SBF1-NB 4927 4332 1856 8.35 SBE4-NC 5031 4371 1873 8.35 ND 5069 4384 1879 8.35 SBE2-NE 5093 4394 1883 8.35 SBE1-NF 5093 4432 1899 8.35 TSDB-Top OA 5319 4462 1913 8.35 I Recommended Bit Program: 1 1 3-1 /2" o - 2748 2748' Saker Hughes MX-1 2 9-7/8" 2,748' - 6,227' 3479' 3 NC/ND 6-3/4" 6,227' - 8,906' 2679' Hycalog DSX-146 OA 6-3/4" 5,346' - 8,898' 3552' Hycalog DSX-146 Page 4 . . Well Control: Intermediate/Production hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity tests: Kick tolerance: · Integrity tests: · Planned completion fluid: / 1,913 psi at 4,432' TVD (OA) 1 ,467 psi at (Based on a full column of gas at 0.1 psi/ft) 3,000 psi FIT to 11 Ib/gal 20' below the 10-3/4" shoe. 55 Bbls with 9.4 Ib/gal mud at below the 10-3/4" shoe. FIT to 1 0 Ib/gal 20' below the 7-5/8" shoe. Kill Weight Brine, with diesel cap, in intermediate. MOBM in liners. Drilling Hazards & Contingencies: · Running Gravel/heavy clay problems have been encountered in some E-Pad wells. High Vis Mud should be utilized. · Hydrates have been reported on E-Pad. Expected Depth for hydrates 2000' SS to 2500' SS. ./ " Keep the Mud as Cool as possible. MW should be 9.8 by the base of the permafrost. Lost Circulation Lost Circulation is not reported as a major problem for E-Pad. Irregardless, of this good drilling practices need to be maintained. Expected Pressures · All Formation are expected to be normally pressured: 8.35 ppg or less. ~ Pad Data Sheet · Please Read the E-Pad Data Sheet thoroughly. Hydrocarbons · Hydrocarbons are possible in the Ugne interval. Faults · Several faults are mapped in the well. Fault #1 in the Upper Ugnu intermediate hole section at 4098' MD(382o' TVDss). Fault #4 is within the OA, near the invert point at 5480'. Fault #5 is mapped in the OA Lateral @ -7200' MD. Faults 1 & 2 are in the NB but should not be intercepted. Hydrogen Sulfide · MPE Pad is not designated as an H2S Pad, H2S detected from E-Pad wells on the pad: tMPE-17' '"' 51 ppm 2/2001 \L~~~\\") MPE-22 46 ppm 2/2001 MPE-04 5 ppm 2/2001 Anti-collision Issues · MPE-32 passes the Major Risk Criteria. The nearest well, is MPE-08, 72' distant at 1867' MD. Distance to Nearest Property · MPE-32 is planned to be 6950 ft from the nearest Milne Point property line. / Distance to Nearest Well Within Pool · MPE-32 is 390 ft from the nearest sand penetration in the MPE-06. ...... \L~~~N\c. ~Q' \ \ Page 5 . . DRILL & COMPLETION PROCEDURE Pre-RiQ Operations 1. The 20" conductor will be installed pre-rig. DrillinQ: 1. MIRT and NU Diverter. 2. Function Test Diverter, PU 4" DP and BHA. 3. Drill 13-1/2" surface hole to the Schrader Bluff interval. 4. Run and cement 10-3/4" surface casing. 4.0 ,,::>~~k.Uë . 5. ND diverter, install wellhead and NU/Test BOPE. 6. Drill 9-7/8" hole to intermediate casing point. 7. Run and cement 7-5/8" intermediate casing. 8. Displace to MOBM. Drill 6-3/4" NC/ND horizontal production hole. 9. Run and set 4" Screens. 10. Run whipstock and mill window for OA lateral. 11. Drill 6-3/4" OA horizontal production hole. 12. Retrieve whipstock. 13. Run 4.5" slotted liner and hang off in 7.625" casing 14. RU and Run 2.875" ESP Completion. 15. ND BOP/NU Tree 16. RDMO Doyon 14. Page 6 . MPE-32 Proposed ,J. ~ 9.2 PPG Versapro MOBM below Completion DATE 04106/2004 REV. BY W. Quay . TREE: 2-9116" 5M WELLHEAD: FMC Gen 5 System 11", 5M Tubing Head: FMC 11" X 2.875" I Orig KB elev (0-14) =' ~ I 109' 27/8" GLM -150' 2-7/S" 6.5 ppf, L-SO, EUE production tubing (Drift ID = 2.347", cap = 0.00579 bpf) Baker ZXP Liner Top Packer & Hanger @ 5,xxx' MD Cameo 2 7/8" x 1" sidepoeket KBMM GLM 2 Jts above ESP \ ""-. I 6,227'-8,906' '\ 6·3/4" NC/ND Lateral 4" Screens ' 27/8" XN Nipple. 1 Jt above ESP .... 10-3/4",45.5# L-SO BTC Csg @ 2,74S' MD Centrilift ESP ~ !í7-5I8" Cas;"" Shoe ~ 8,227' MD I J T\-., "\ '> ~(t~\-t/ Baker Hookwall Hanger @ x,xxx' MD Window in 7-5/8" easing@ 5,346' M Well Inclination @ Window = 80° , Bake Flexlock Liner Hanger Bak ZXP Liner Top Packer & Han r @ . MD I 5,346-8,898' I 6-3/4" OA Lateral 4-1/2" Slotted ~ ( " ~ COMM""TS 7-5/8",29.7#, L-80, BTC-M Casing Drift: 6.75" Calsing 10: 6.875" " / / -~ Proposed Inverted Multilateral Milne Point WELL: E-32ML API NO: 50-029- 50-029- 50-029- . . MPU E-PAD o .'<1' '<I' :'t" (Q f") ~~ ö: ~ U/G FIBEROPTIC CABLE \<.0 þ..\) ?O\~\ U/G ELECTRIC- "'\\-,.~ (L------~E~~~5.00 ------: -______________,§ \\ + U/G PIPING ~ I /?------W~ ~ N 2600 I 0 "" ! / '\ 1 I Z~ ! / I 1 I ~ ~ : / 7--ABANDONED ' 1 : ~w ¡ / U/G PIPING ~:_ I I / I .J::j" ~/ ! U/G ELECTRIC~ ]:.1 (~--~~-7-- _~_8______ -'~: : DESIGN . '" V'I DESIGN SHOULDER I N 2400.00 30.0~/ '" U/G ELECTRIC . 33 _I NCJŒoU/~-=~ E-27-'" · 2 ~¡ ~ 'V -$-E-32 ¡ ~ ~ 1 0 . -$- E - 31 ; Ì'- AS-BUILT SHOULDER 260' ~ ~ E-2&t7 . 4 H GRAVEL .... ~ 22. . 1 "I EXPANSION"'~ ~ 29"1. "- ~ ~: "- NOMINAL DESIGN TOE ~ 13 . . 5 :: ~~ 26. . 30 :: (N 2150) : 9 . . 6 ;: AS-BUILT SHOULDER : 25 . . 21 ;: 1 1 A 11. . 7 :: DESIGN SHOULDER W' 1 8 . . 1 6 - 1 I <.:> -I : g 20. . 23 :1 1 > :: GRAVEL I 4: 24 . . 19 ;VEXPANSION :~ 14. .12 I ¡D -:.J-5.o· I I 15. . 17 ;1 I VI ! I ~ 8;1,.... '0 ··10 I O'J t3~;!m I ~ -1.0·1.... I ~ ~~;!w I w N 1820 ow' 1'-' L_____________________________J + ,- -~- I NOTE: u/a B.ECTFIC 700' o o o w (N 1820) N 1800 + NOTES LEGEND -$- PROPOSED CONDUCTORS . EXISTING WELL CONDUCTOR 1. COORDINATES SHOWN ARE MPU E-PAD PLANT COORDINATES. 2. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MONUMENTS CFP-3 AND E-1. 3. ELEVATIONS ARE BPX MILNE POINT DATUM M.S.L. 4. HAZARDS SHOWN PER MPU E-PAD UNDERGROUND HAZARD LOCATION ALERT DRAWING (CE-ME-CN-0006-002 REV.1) Þ~O__~_'~ ~.~ ]lD 'W DRA~NG ¡ ff]~~[I)œD JOB NO .&tr lOH :GI= =D ~ SCALE: BY CHK ................... """ NOT TO SCALE JMF CHECKED: LOH DATE; 3/23/05 ObP o 3/23/05 ISSUED FOR ACIWI INFORMA11ON NO. DATE RE\IISlON MILNE POINT UNIT E-PAD 2005 ACWR GRAVEL EXPANSION FOR DRILL RIG ACCESS SHEET; 1 OF 1 No. TVD COMPA},IY DETAIlS BP Amoœ CASING DETAILS MD Name 7 4 0-- j..... - . - - 900-- Size 10.750 7.625 4.500 No. TVDPafu 1 2 3 4 5 6 7 8 9 10 11 12 : 13 REFERENCE INFORMATION FORMATION TOP DETAILS MDPath Formation Start Dír 11100' 400' MD, 4OO'TVD ----- Start Dir 2/100' : 900' MD,899.37'TVD ~ StartDir31J00': J100'MD, 1097.83'TVD 8m" Oir 1.51100': 1400' MO, 1389.25'TVD - , -, 1800-- - - " ~ '" - '" i?:;, - fa - "" " - " " 2700 i. " € -¡iirl¡··.i.... :: " ~. ...... þ _. : ... .... 4500 - ; - '; í."'E _. "," ,[ o _. - . .. , : ! I ¡ ¡ f End Dir : 153333' MD, 1515.31' TVO F¡=~ E4-J. E2-NE ;;C;;;:;;"'''': .~ up Start Oir4l100': 1995.92' MO, !950'TVD . - EndDir: 1998.7'MD, 1952.61'TVO 8m" Oir 4/100': 3491.05' MO, 3355.54'fVD IF '" PA'" I 900 ¡ ¡ I I I ¡ t I ¡ SURVEY PROGRAM Depth Fm Depth To SurveyIPlnn 3430 12t'KHiO 1200J)1) 8906.81 See MD Inc Azi ¡ 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 T=' CB~GYRo.SS MWû+fFR+MS SECTION DETAILS TVD +NI-S ¡ 1 ¡ ¡ :¡ Name 'op 'oP' : 4806.48' MD, 4286.61' TVD Start Dir6lIoo': 513758' MD, 4410.64'TVD I : 1800 , , , , , End Dir : 5772.79' MD, 4445.9' TVO Start Dír 61100' : 5%5.08' MO, 4393.69'TVO N~ Plan M?E-32 End Dir : 6227.69' MD, 4357.8' TVD t Start Dir 61100' : 6247.69' MD, 4357.8'fV0 End Dir : 6261' MD, 4357.71' TVD Start Dir 41100' - ,- End Dir : 0..0.7 ,~v, ~.w.55' 1/;/ ,~~"W, """·~.'ill~" ;; Ii ; ;; ;1 I I ; : : : : . jT f~a.,¡; I I í . I , I I . , j ¡ 1 ¡ \ I 11 ¡ 4500 ¡ ¡ 1 I ¡ ¡ ¡ j 1¡ 5400 Chec-ked: Plan: MPE~32 wplO (film MPE~32JMPE<n) Date: Creared By: Digital Bw;iness Client User Date: 3116/2005 +EI-W TVD Reviewed: DLeg TFace TARGET DETAILS +NI,S +Ð·W +EI-W Northing Date: VSec Target MPE-32 T1 Top NB MPE-32 T2 Top OA MPE-32 T3 Ba"" NCIND MPE-32 T4 Mid NCIND MPE-32 T5 MI'E-32 Northing Basting Shape WELL DETAILS Easting Ûttitude Longitude Slot ~305.œ 6016520.69 5691 Hlj4 ïW21'19.184N 149"16'09b15W NlA 32 T6 Mid NCIND '2" 32 32 wpJO : 89!)6,81' MD, 4382 .. ¡ ¡ j ¡ ! Ax; Plan, MPß,32 wpW (Ph" MPE·32IMPE,32) Created By: Digital Business Client User Date: 3/16/2005 Checked: Date: - WELL DETAILS NOrthing - """"'" Longitude SID' 6016520..69 569110.34 71)"21'19,7ß4N !49"26W.615W TARGET DETAILS +NI·g +EI·W Northing Easting Shape Poi Poi Po! PO! PoJ Pot POI Poi Poi PoJ Poi PoJ PoJ CASING DETAiLS No. TVD MD Name Size 0 0 9 4 FORMATION TOP DETAILS No. TVDPath MDPath 'mati( 1 2 3 4 5 6 7 8 9 !() l! 12 13 6300 SURVEY PROGRAM Depth Fm Depth T\) Survey/Plan TQol 3430 1200.00 WV78 Cß-.GYRO-SS lZOO,OO 89ú6.81 10"'" MWD+IFR+MS I Name Plan MPE-31 2725.23 -305.03 Name TVD NB OA itEFEREN(;E INFORMATION OOMPANY DETAILS BP Arnow ;;ECfION DETAiLS TVD +NI·S +EI·W DLeg Thee VSec Target MpE-32 T1 Top NB MpE-32 T2 Top OA MPE-32 T3 Base NCIND MpE·32 T4 Mid NCIND MpE-32 T5 Mid NCIND MpE·32 T6 Mid NCIND Ioe MD See 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 '"a" :Iii "" "" D +' f ~ i is tI:J . . Sperry-Sun BP Planning Report Plan Section Information ft 6247.69 90.00 98.00 4357.80 97.22 2989.81 0.00 0.00 0.00 0.00 6261.00 90.77 97.81 4357.71 95.39 3002.98 6.00 5.82 -1.44 -13.93 6630.05 90.77 97.81 4352.72 45.26 3368.58 0.00 0.00 0.00 0.00 6682.52 89.05 99.00 4352.80 37.59 3420.48 4.00 -3.29 2.27 145.38 MPE-32 T4 Mid NC/ND 6726.97 89.02 100.78 4353.55 29.96 3464.26 4.00 -0.07 4.00 91.04 7415.97 89.02 100.78 4365.38 -98.87 4141.01 0.00 0.00 0.00 0.00 7585.62 89.35 94.00 4367.80 -120.67 4309.13 4.00 0.20 -4.00 -87.20 MPE-32 T5 Mid NC/ND 7728.90 89.35 88.27 4369.42 -123.51 4452.32 4.00 0.00 -4.00 -90.07 8906.81 89.35 88.27 4382.80 -87.92 5629.62 0.00 0.00 0.00 0.00 MPE-32 T6 Mid NC/ND Survey Sys 1VD NIS EIW ft ft ft 34.30 0.00 0.00 34.30 -23.50 0.00 0.00 0.00 6016520.69 569110.34 CB-GYRO-SS 100.00 0.00 0.00 100.00 42.20 0.00 0.00 0.00 6016520.69 569110.34 CB-GYRO-SS 200.00 0.00 0.00 200.00 142.20 0.00 0.00 0.00 6016520.69 569110.34 CB-GYRO-SS 300.00 0.00 0.00 300.00 242.20 0.00 0.00 0.00 6016520.69 569110.34 CB-GYRO-SS 400.00 0.00/ 0.00 400.00 342.20 0.00 0.00 0.00 6016520.69 569110.34 Start Dir 1/100 500.00 1.00 65.00 499.99 442.19 0.37 0.79 1.00 6016521.07 569111.13 CB-GYRO-SS 600.00 2.00 65.00 599.96 542.16 1.48 3.16 1.00 6016522.19 569113.49 CB-GYRO-SS 700.00 3.00 65.00 699.86 642.06 3.32 7.12 1.00 6016524.07 569117.42 CB-GYRO-SS 800.00 4.00 65.00 799.68 741.88 5.90 12.65 1.00 6016526.70 569122.93 CB-GYRO-SS 900.00 5.00 65.00 899.37 841,57 9.21 19.76 1.00 6016530.09 569130.01 Start Dir 2/100 1000.00 7.00 65.00 998.81 941.01 13.63 29.23 2.00 6016534.59 569139.44 CB-GYRO-SS 1100.00 9.00 65.00 1097.83 1040,03 19.51 41.85 2.00 6016540.59 569152.00 Start Dir 31100 1200.00 12.00 65.00 1196.15 1138.35 27.21 58.36 3.00 6016548.44 569168.44 MWD+IFR+MS 1300.00 15.00 65.00 1293.37 1235.57 37.08 79.51 3.00 6016558.50 569189.50 MWD+IFR+MS 1400.00 18.00 65.00 1389.25 1331.45 49.08 105.25 3.00 6016570.74 569215.12 Start Dir 1.5/1 1500.00 19.50 65.00 1483.94 1426.14 62.66 134.38 1.50 6016584.59 569244.12 MWD+IFR+MS 1533.33 20.00 65.00 1515.31 1457.51 67.42 144.59 1.50 6016589.45 569254.29 End Dir : 1533 1600.00 20.00 65.00 1577.95 1520.15 77.06 165.26 0.00 6016599.27 569274.86 MWD+IFR+MS 1700.00 20.00 65.00 1671.92 1614.12 91.52 196.26 0.00 6016614.01 569305.72 MWD+IFR+MS 1800.00 20.00 65.00 1765.89 1708.09 105.97 227.25 0.00 6016628.75 569336.58 MWD+IFR+MS 1900.00 20.00 65.00 1859.86 1802.06 120.42 258.25 0.00 6016643.49 569367.44 MWD+IFR+MS 1982.94 20.00 65.00 1937.80 1880.00 132.41 283.96 0.00 6016655.72 569393.03 BPRF 1995.92 20.00 65.00 1950.00 1892.20 134.29 287.98 0.00 6016657.63 569397.04 Start Dir 4/100 1998.70 19.93 65.26 1952.61 1894.81 134.69 288.84 4.00 6016658.04 569397.90 End Dir : 1998 2000.00 19.93 65.26 1953.83 1896.03 134.87 289.25 0.00 6016658.23 569398.30 MWD+IFR+MS 2100.00 19.93 65.26 2047.84 1990.04 149.14 320.21 0.00 6016672.78 569429.13 MWD+IFR+MS 2200.00 19.93 65.26 2141.85 2084.05 163.41 351.18 0.00 6016687.33 569459.95 MWD+IFR+MS 2300.00 19.93 65.26 2235.86 2178.06 177.67 382.14 0.00 6016701.88 569490.78 MWD+IFR+MS 2400.00 19.93 65.26 2329.87 2272.07 191.94 413.11 0.00 6016716.44 569521.61 MWD+IFR+MS 2500.00 19.93 65.26 2423.87 2366.07 206.21 444.08 0.00 6016730.99 569552.44 MWD+IFR+MS 2600.00 19.93 65,26 2517.88 2460.08 220.48 475.04 0.00 6016745.54 569583.27 MWD+IFR+MS 2700.00 19.93 65.26 2611.89 2554.09 234.74 506.01 0.00 6016760.09 569614.10 MWD+IFR+MS 2748.83 19.93 65.26 2657.80 2600.00 241.71 521.13 0.00 6016767,20 569629.16 10314" 2800.00 19.93 65.26 2705.90 2648.10 249.01 536.97 0.00 6016774.65 569644.93 MWD+IFR+MS 2900,00 19.93 65.26 2799.91 2742.11 263.28 567.94 0.00 6016789.20 569675.76 MWD+IFR+MS 3000.00 19.93 65.26 2893.92 2836.12 277.54 598.90 0.00 6016803.75 569706.59 MWD+IFR+MS 3100.00 19.93 65.26 2987.92 2930.12 291.81 629.87 0.00 6016818.30 569737.42 MWD+IFR+MS 3200.00 19.93 65.26 3081.93 3024.13 306.08 660.84 0.00 6016832.86 569768.25 MWD+IFR+MS 3300.00 19.93 65.26 3175.94 3118.14 320.34 691.80 0.00 6016847.41 569799.08 MWD+IFR+MS 3400.00 19.93 65.26 3269.95 3212.15 334.61 722.77 0.00 6016861.96 569829.90 MWD+IFR+MS 3491.05 19.93 65.26 3355.54 3297.74 347.60 750.96 0.00 6016875.21 569857.97 Start Dir 4/100 . . Sperry-SuD BP Planning Report Survey MD NIS DLS MapN ft ft deg/100ft ft 3500.00 20.20 65.98 3363.95 3306.15 348.87 753.76 4.00 6016876.50 569860.76 MWD+IFR+MS 3600.00 23.28 72.89 3456.85 3399.05 361.72 788.42 4.00 6016889.67 569895.30 MWD+IFR+MS 3700.00 26.59 78.21 3547.52 3489.72 372.11 829.23 4.00 6016900.44 569936.01 MWD+IFR+MS 3800.00 30.06 82.40 3635.54 3577.74 380.00 875.99 4.00 6016908.76 569982.68 MWD+IFR+MS 3900.00 33.64 85.79 3720.48 3662.68 385.35 928.46 4.00 6016914.60 570035.10 MWD+IFR+MS 3994.84 37.11 88.46 3797.80 3740.00 388.05 983.29 4.00 6016917.80 570089.89 TUZC 4000.00 37.30 88.59 3801.91 3744.11 388.13 986.40 4.00 6016917.91 570093.01 MWD+IFR+MS 4097.82 40.93 90.91 3877.80 3820.00 388.35 1048.10 4.00 6016918.71 570154.69 MPE-32 Fault 1 4100.00 41.01 90.96 3879.44 3821.64 388.33 1049.52 4.00 6016918.70 570156.12 MWD+IFR+MS 4200.00 44.76 92.99 3952.70 3894.90 385.94 1117.52 4.00 6016916.94 570224.12 MWD+IFR+MS 4300.00 48.55 94.77 4021.33 3963.53 380.99 1190.05 4.00 6016912.66 570296.70 MWD+IFR+MS 4349.99 50.45 95.58 4053.80 3996,00 377.55 1227.91 4.00 6016909.58 570334.58 Ugnu-MA 4365.80 51.05 95.83 4063.80 4006.00 376.33 1240.09 4.00 6016908.48 570346.77 Ugnu-MB1 4400.00 52.36 96.35 4084.99 4027.19 373.48 1266.78 4.00 6016905.87 570373.48 MWD+IFR+MS 4472.38 55.13 97.40 4127.80 4070.00 366.49 1324.72 4.00 6016899.41 570431.48 Ugnu-MB2 4500.00 56.19 97.78 4143.38 4085.58 363.47 1347.32 4.00 6016896.61 570454.10 MWD+IFR+MS 4600.00 60.03 99.09 4196.20 4138.40 351.00 1431.29 4.00 6016884.92 570538.17 MWD+IFR+MS 4700.00 63.88 100.30 4243.21 4185.41 336.12 1518.26 4.00 6016870.85 570625.28 MWD+IFR+MS 4793.78 67.51 101.36 4281.80 4224.00 320.06 1602.19 4.00 6016855.57 570709.34 Ugnu-MC 4800.00 67.75 101.43 4284.17 4226.37 318.92 1607.83 4.00 6016854.48 570714.99 MWD+IFR+MS 4806.48 68.00 101.50 4286.61 4228.81 317.73 1613.71 4.00 6016853.34 570720.89 End Dir : 4806 4836.35 68.00 101.50 4297.80 4240.00 312.21 1640.86 0.00 6016848.07 570748.08 MPE-32 Fault 2 4865.72 68.00 101.50 4308.80 4251.00 306.78 1667.54 0.00 6016842,89 570774.80 SBF2-NA 4900.00 68.00 101.50 4321.64 4263.84 300.44 1698.68 0.00 6016836.85 570806.00 MWD+IFR+MS 4916.44 68.00 101.50 4327.80 4270.00 297.40 1713.62 0.00 6016833.95 570820.96 MPE-32 Fault 3 4927.12 68.00 101.50 4331.80 4274.00 295.43 1723.32 0.00 6016832.06 570830.68 SBF1-NB 4956.48 68.00 101.50 4342.80 4285.00 290.00 1750.00 0.00 6016826.88 570857.41 MPE-32 T1 Top ~ 5000.00 68.00 101.50 4359.10 4301.30 281.96 1789.54 0.00 6016819.21 570897.02 MWD+IFR+MS 5031,23 68.00 101.50 4370.80 4313.00 276.18 1817.91 0.00 6016813.70 570925.44 SBE4-NC 5068.60 68.00 101.50 4384.80 4327.00 269.28 1851.87 0.00 6016807.11 570959.45 NO 5092.62 68.00 101.50 4393.80 4336.00 264.83 1873.70 0.00 6016802.87 570981.32 SBE2-NE 5100.00 68.00 101.50 4396.56 4338.76 263.47 1880.40 0.00 6016801.57 570988.04 MWD+IFR+MS 5137.58 68.00 101.50 4410.64 4352.84 256.52 1914.54 0.00 6016794.94 571022.24 Start Dir 6/1 00 5198.82 71.57 100.56 4431.80 4374.00 245.54 1970.94 6.00 6016784.48 571078.73 SBE1-NF 5200.00 71,64 100.54 4432.17 4374.37 245.33 1972.04 6.00 6016784.28 571079.83 MWD+IFR+MS 5254.11 74.79 99.74 4447.80 4390.00 236.22 2023.03 6.00 6016775.64 571130.90 MPE-32 Fault 5 5300.00 77.47 99.08 4458.80 4401.00 228.93 2066.98 6.00 6016768.76 571174.91 MWD+IFR+MS 5319.29 78.59 98.81 4462.80 4405.00 226.00 2085.62 6.00 6016766.00 571193.57 TSBD-Top OA 5346.44 80.18 98.43 4467.80 4410.00 222.00 2112.00 6.00 6016762.25 571219.99 MPE-32 T2 Top 0 5400.00 83.39 98.37 4475.45 4417.65 214.26 2164.44 6.00 6016755.00 571272.49 MWD+IFR+MS 5500.00 89.39 98.27 4481.74 4423.94 199.82 2263.14 6.00 6016741.48 571371.32 MWD+IFR+MS 5600.00 95.39 98.16 4477.57 4419.77 185.55 2361.98 6.00 6016728.13 571470.28 MWD+IFR+MS 5700.00 101.39 98.06 4462.98 4405.18 171.60 2459.88 6.00 6016715.08 571568.29 MWD+IFR+MS 5772.79 105.76 97.98 4445.90 4388.10 161.73 2529.93 6.00 6016705.87 571638.42 End Dir : 5772 5800.00 105.76 97.98 4438.51 4380.71 158.10 2555.86 0.00 6016702.47 571664.38 MWD+IFR+MS 5900.00 105.76 97.98 4411.36 4353.56 144.74 2651.17 0.00 6016690.00 571759.80 MWD+IFR+MS 5965.08 105.76 97.98 4393.69 4335.89 136.05 2713.20 0.00 6016681.88 571821.90 Start Dir 6/100 6000.00 103.66 97.98 4384.82 4327.02 131.36 2746.65 6.00 6016677.50 571855.39 MWD+IFR+MS 6100.00 97.66 97.99 4366.33 4308.53 117.71 2843.92 6.00 6016664.76 571952.78 MWD+IFR+MS 6200.00 91.66 98.00 4358.20 4300.40 103.86 2942.58 6.00 6016651.83 572051.55 MWD+IFR+MS 6227.00 90.04 98.00 4357.80 4300.00 100.10 2969.31 6.00 6016648.32 572078.31 7 5/8" 6227.69 90.00 98.00 4357.80 4300.00 100.00 2970.00 6.00 6016648.23 572079.00 MPE-32 T3 Bas~ 6247.69 90.00 98.00 4357.80 4300.00 97.22 2989.81 0.00 6016645.63 572098.83 Start Dir 6/100 . . Sperry-Sun BP Planning Report Survey 6261.00 90.77 97.81 4357.71 4299.91 95.39 3002.98 6.00 6016643.92 572112.03 End Dir : 6261 6300.00 90.77 97.81 4357.18 4299.38 90.09 3041.62 0.00 6016638.98 572150.70 MWD+IFR+MS 6400.00 90.77 97.81 4355.83 4298.03 76.51 3140.68 0.00 6016626.32 572249.88 MWD+IFR+MS 6500.00 90.77 97.81 4354.48 4296.68 62.92 3239.75 0.00 6016613.66 572349.06 MWD+IFR+MS 6600.00 90.77 97.81 4353.13 4295.33 49.34 3338.81 0.00 6016600.99 572448.23 MWD+IFR+MS 6630.05 90.77 97.81 4352.72 4294.92 45.26 3368.58 0.00 6016597.19 572478.04 Start Dir 4/1 00 6682.52 89.05 99.00 4352.80 4295.00 37.59 3420.48 4.00 6016590.00 572530.00 MPE-32 T4 Mid 1\ 6700.00 89.04 99.70 4353.09 4295.29 34.75 3437.73 4.00 6016587.32 572547.27 MWD+IFR+MS 6726.97 89.02 100.78 4353.55 4295.75 29.96 3464.26 4.00 6016582.78 572573.85 End Dir : 6726 6800.00 89.02 100.78 4354.81 4297.01 16.30 3535.99 0.00 6016569.79 572645.70 MWD+IFR+MS 6900.00 89.02 100.78 4356.52 4298.72 -2.40 3634.22 0.00 6016552.00 572744.08 MWD+IFR+MS 7000.00 89.02 100.78 4358.24 4300.44 -21.09 3732.44 0.00 6016534.22 572842.46 MWD+IFR+MS 7100.00 89.02 100.78 4359.96 4302.16 -39.79 3830.66 0.00 6016516.44 572940.84 MWD+IFR+MS 7200.00 89.02 100.78 4361.67 4303.87 -58.49 3928.88 0.00 6016498.65 573039.22 MWD+IFR+MS 7300,00 89.02 100.78 4363.39 4305.59 -77.19 4027.10 0.00 6016480.87 573137.60 MWD+IFR+MS 7400.00 89.02 100.78 4365.11 4307.31 -95.89 4125.32 0.00 6016463.08 573235.98 MWD+IFR+MS 7415.97 89.02 100.78 4365.38 4307.58 -98.87 4141.01 0.00 6016460.24 573251.70 Start Dir 4/100 7500.00 89.18 97.42 4366.71 4308.91 -112.16 4223.96 4.00 6016447.73 573334.76 MWD+IFR+MS 7585.62 89.35 94.00 4367.80 4310.00 -120.67 4309.13 4.00 6016440.00 573420.00 MPE-32 T5 Mid 1\ 7600.00 89.35 93.42 4367.96 4310.16 -121.60 4323.48 4.00 6016439.20 573434.36 MWD+IFR+MS 7700.00 89.35 89.42 4369.10 4311.30 -124.09 4423.43 4.00 6016437.65 573534.31 MWD+IFR+MS 7728.90 89.35 88.27 4369.42 4311.62 -123.51 4452.32 4.00 6016438.50 573563.19 End Dir : 7728 7800.00 89.35 88.27 4370.23 4312.43 -121.36 4523.38 0.00 6016441.30 573634.22 MWD+IFR+MS 7900.00 89.35 88.27 4371.37 4313.57 -118.34 4623.33 0.00 6016445.25 573734.13 MWD+IFR+MS 8000.00 89.35 88.27 4372.50 4314.70 -115.32 4723.28 0.00 6016449.20 573834.04 MWD+IFR+MS 8100.00 89.35 88.27 4373.64 4315.84 -112.30 4823.22 0.00 6016453.15 573933.94 MWD+IFR+MS 8200.00 89.35 88.27 4374.77 4316.97 -109.27 4923.17 0.00 6016457.10 574033.85 MWD+IFR+MS 8300.00 89.35 88.27 4375.91 4318.11 -106.25 5023.12 0.00 6016461.04 574133.75 MWD+IFR+MS 8400.00 89.35 88.27 4377.04 4319.24 -103.23 5123.07 0.00 6016464.99 574233.66 MWD+IFR+MS 8500.00 89.35 88.27 4378.18 4320.38 -100.21 5223.02 0.00 6016468.94 574333.57 MWD+IFR+MS 8600.00 89.35 88.27 4379.32 4321.52 -97.19 5322.96 0.00 6016472.89 574433.47 MWD+IFR+MS 8700.00 89.35 88.27 4380.45 4322.65 -94.17 5422.91 0.00 6016476.84 574533.38 MWD+IFR+MS 8800.00 89.35 88.27 4381.59 4323.79 -91.14 5522.86 0.00 6016480.79 574633.29 MWD+IFR+MS 8900.00 89.35 88.27 4382.72 4324.92 -88.12 5622.81 0.00 6016484.73 574733.19 MWD+IFR+MS 8906.00 89.35 88.27 4382.79 4324.99 -87.94 5628.80 0.00 6016484.97 574739.19 4112" 8906.81 / 89.35 88.27 4382.80 . 4325.00 -87.92 5629.62 0.00 6016485.00 574740.00 MPE-32 T6 Mid 1\ . . Sperry-SuD BP Planning Report Company: Field: Site: WeB: ·WeBpath: BP Amoco MUne Point MptEPad Plan MPE-32 MPE-32 Date: 3116/2005 TIme: 12:54:47 Page: Co-ordlnate(NE) Reference: Well: Plan MPE-32. True Nòrth _ Vertkal (TVD) Reference: 34.3 + 23.5 57.8 Sedion (VS) Reference: Well (O.OON,O.OOE,90.89Azi) .. . Snrvey Calealation Method.: Minimum Curvature '" . Db: Oracle Plan: MPE-32 wp10 Date Composed: Version: Tied-to: 1/1712005 78 From Well Ref. Point Principal: Yes Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt E Pad TR-13-10 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Well: Plan MPE-32 Goldberry Well Position: +N/-S +E/-W Position Uncertainty: 2725.23 ft Nortbing: -305.03 ft Easting: 0.00 ft 6013798.68 ft Latitude: 70 26 52.982 N 569440.72 ft Longitude: 149 26 0.655 W Nortb Reference: True Grid Convergence: 0.53 deg Slot Name: 6016520.69 ft / Latitude: 70 27 19.784 N 569110.34 ft / Longitude: 149 26 9.615 W Casing Points MD TVD Diameter Hole Size Name ft ft in in 2748.83 2657.80 10.750 12.250 10314" 6227.00 4357.80 7.625 9.875 7 5/8" 8906.00 4382.79 4.500 6.750 4 112" Formations MD TVD Formations lithology DipADgk: Dlp~tioJl. ft ft ~ ~ 1982.94 1937.80 BPRF 0.00 0.00 3994.84 3797.80 TUZC 0.00 0.00 4349.99 4053.80 Ugnu-MA 0.00 0.00 4365.80 4063.80 Ugnu-MB1 0.00 0.00 4472.38 4127.80 Ugnu-MB2 0.00 0.00 4793.78 4281.80 Ugnu-MC 0.00 0.00 4865.72 4308.80 SBF2-NA 0.00 0.00 4927.12 4331.80 SBF1-NB 0.00 0.00 5031.23 4370.80 SBE4-NC 0.00 0.00 5068.60 4384.80 NO 0.00 0.00 5092.62 4393.80 SBE2-NE 0.00 0.00 5198.82 4431.80 SBE1-NF 0.00 0.00 5319.29 4462.80 TSBD-Top OA 0.00 0.00 0.00 TSBC-Base OA 0.00 0.00 Targets Map Map <.-. Latitude ~ ·~JîØ~de ~ Name . Deseription TVD +N/-5 +EI-W Nortbing Eas(blg peg MIn See peg ~ See OW· Dir. ft ft ft ft ft MPE-32 Fault 1 3877.80 887.90 1243.07 6017420.00 570345.00 70 27 28.516 N 149 25 33.095 W -Polygon 1 3877.80 887.90 1243.07 6017420.00 570345.00 70 27 28.516 N 149 25 33.095 W -Polygon 2 3877.80 387.71 1040.40 6016918.00 570147.00 70 27 23.597 N 149 25 39.051 W -Polygon 3 3877.80 -17.92 779.60 6016510.00 569890.00 70 27 19.608 N 149 25 46.714 W -Polygon 4 3877.80 387.71 1040.40 6016918.00 570147.00 70 27 23.597 N 149 25 39.051 W MPE-32 Fault 2 4297.80 492.37 1294.40 6017025.00 570400.00 70 27 24.626 N 149 25 31.589 W -Polygon 1 4297.80 492.37 1294.40 6017025.00 570400.00 70 27 24.626 N 149 25 31.589 W -Polygon 2 4297.80 -167.52 1273.28 6016365.00 570385.00 70 27 18.136 N 149 25 32.213 W MPE-32 Fault 3 4327.80 439.77 1573.96 6016975.00 570680.00 70 27 24.108 N 149 25 23.377 W . . Sperry-SuD BP Planning Report Targets ft ft -Polygon 1 4327.80 439.77 1573.96 6016975.00 570680.00 70 27 24.108 N 149 25 23.377 W -Polygon 2 4327.80 -145.13 1554.53 6016390.00 570666.00 70 27 18.355 N 149 25 23.951 W MPE-32 T1 Top NB 4342.80 290.00 1750.00 6016826.88 570857.41 70 27 22.634 N 149 25 18.206 W MPE-32 Poly 4342.80 190.06 1539.63 6016725.00 570648.00 70 27 21.652 N 149 25 24.386 W -Polygon 1 4342.80 441.08 1648.98 6016977.00 570755.00 70 27 24.120 N 149 25 21.173 W -Polygon 2 4342.80 215.47 1602.88 6016751.00 570711.00 70 27 21.902 N 149 25 22.528 W -Polygon 3 4342.80 -218.91 4333.23 6016342.00 573445.00 70 27 17.619 N 149 24 2.328 W -Polygon 4 4342.80 -182.32 5778.76 6016392.00 574890.00 70 27 17.969 N 149 23 19.865 W -Polygon 5 4342.80 6.81 5767.52 6016581.00 574877.00 70 27 19.829 N 149 23 20.191 W -Polygon 6 4342.80 -11.07 4353.16 6016550.00 573463.00 70 27 19.663 N 149 24 1.739 W -Polygon 7 4342.80 294.55 2565.74 6016839.00 571673.00 70 27 22.677 N 149 24 54.242 W MPE-32 T4 Mid NCIND 4352.80 37.59 3420.48 6016590.00 572530.00 70 27 20.146 N 149 24 29.136 W MPE-32 T3 Base NC/ND 4357.80 100.00 2970.00 6016648.23 572079.00 70 27 20.762 N 149 24 42.369 W MPE-32 T5 Mid NC/ND 4367.80 -120.67 4309.13 6016440.00 573420.00 70 27 18.585 N 149 24 3.034 W MPE-32 T6 Mid NC/ND 4382.80 -87.92 5629.62 6016485.00 574740.00 70 27 18.899 N 149 23 24.244 W MPE-32 Fault 5 4447.80 157.64 3416.59 6016710.00 572525.00 70 27 21.327 N 149 24 29.249 W -Polygon 1 4447.80 157.64 3416.59 6016710.00 572525.00 70 27 21.327 N 149 24 29.249 W -Polygon 2 4447.80 -107.15 3929.21 6016450.00 573040.00 70 27 18.720 N 149 24 14.194 W MPE-32 T2 Top OA 4467.80 222.00 2112.00 6016762.25 571219.99 70 27 21.965 N 149 25 7.572 W MPE-32 Fault 4 4477.80 268.55 2242.46 6016810.00 571350.00 70 27 22.422 N 149 25 3.739 W -Polygon 1 4477.80 268.55 2242.46 6016810.00 571350.00 70 27 22.422 N 149 25 3.739 W -Polygon 2 4477.80 -81.31 2653.27 6016464.00 571764.00 70 27 18.980 N 149 24 51.675 W MPE-32 Fault 6 4507.80 72.89 2310.65 6016615.00 571420.00 70 27 20.498 N 149 25 1.738 W -Polygon 1 4507.80 72.89 2310.65 6016615.00 571420.00 70 27 20.498 N 149 25 1.738 W -Polygon 2 4507.80 -136.19 2746.77 6016410.00 571858,00 70 27 18.440 N 149 24 48.929 W -Polygon 3 4507.80 -277.90 4007.63 6016280.00 573120.00 70 27 17.041 N 149 24 11.893 W -Polygon 4 4507.80 -450.33 4806.14 6016115.00 573920.00 70 27 15.340 N 149 23 48.440 W -Polygon 5 4507.80 -546.20 6515.49 6016035.00 575630.00 70 27 14.385 N 149 22 58.233 W -Polygon 6 4507.80 -450.33 4806.14 6016115.00 573920.00 70 27 15.340 N 149 23 48.440 W -Polygon 7 4507.80 -277.90 4007.63 6016280.00 573120.00 70 27 17.041 N 149 24 11.893 W -Polygon 8 4507.80 -136.19 2746.77 6016410.00 571858.00 70 27 18.440 N 149 24 48.929 W Plan Section Information 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 900.00 5.00 65.00 899.37 9.21 19.76 1.00 1.00 0.00 65.00 1100.00 9.00 65.00 1097.83 19.51 41.85 2.00 2.00 0.00 0.00 1400.00 18.00 65.00 1389.25 49.08 105.25 3.00 3.00 0.00 0.00 1533.33 20.00 65.00 1515.31 67.42 144.59 1.50 1.50 0.00 0.00 1995.92 20.00 65.00 1950.00 134.29 287.98 0.00 0.00 0.00 0.00 1998.70 19.93 65.26 1952.61 134.69 288.84 4.00 -2.36 9.46 126.30 3491.05 19.93 65.26 3355.54 347.60 750.96 0.00 0.00 0.00 0.00 4806.48 68.00 101.50 4286.61 317.73 1613.71 4.00 3.65 2.75 43.61 4956.48 68.00 101.50 4342.80 290.00 1750.00 0.00 0.00 0.00 0.00 MPE-32 T1 Top NB 5137.58 68.00 101.50 4410.64 256.52 1914.54 0.00 0.00 0.00 0.00 5346.44 80.18 98.43 4467.80 222.00 2112.00 6.00 5.83 -1.47 -14.09 MPE-32 T2 Top OA 5772.79 105.76 97.98 4445.90 161.73 2529.93 6.00 6.00 -0.11 -1.00 5965.08 105.76 97.98 4393.69 136.05 2713.20 0.00 0.00 0.00 0.00 6227.69 90.00 98.00 4357.80 100.00 2970.00 6.00 -6.00 0.01 179.92 MPE-32 T3 Base NC/ND C'OMPANYDETA1t$ SURVEY PROGRAM BPAI'I1/XìO Depth Fm Depth To 8urwyfPlM Too' 1200,00 CB-GYRQ..SS 8906.81 MWD+[FR+MS d :asi WELLPATH DETAILS From Colour ToMD 34 500 500 1000 343+23.5 51,00ft Origin Origin 8œmng +Nf-S +E!·W From 'IVD 90.89" 0.00 0.00 :J:4j{ lE~1) 14500 vSec TiU'get MPfH2 Tl TßP NB MPE-32 T2 Top OA MP£·32 T3 Base NCiND MP£.32 14 Mid NCIND TF", SECTION OO'f.AJLS +E!-W Dt.eg TV!> Ari In< MD "" I 2 3 4 5 . 1 S ~ 10- J! 12 U 14 15 ,. 17 !% 19 ::ro 21 z¡ 13 24 /2S ANTI·COLLlSION SETIINGS WELL DETAILS N_ +N!.,g +Ei-W Northing - Laritude t.on;¡- Sfo< P!ro:ì MP£..32 272523 ·305.03 6016520.69 5691lO.34 70"27'19.7&4N 149"26'Q9Æ15W NfA -80 -50 -'38 -0 -13 -25 -38 -50 -63 -80 Company: BPAmoco Field: Milne Point Reference Site: M pt E Pad Reference WeD: Plan MPE-32 Reference WeDpath: MPE-32 GLOBAL SCAN APPLIED: AU weUpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 34.30 to 8906.81 ft Maximum Radius: 1087.25 ft Survey Program for Definitive WeUpath Date: 1/17/2005 Validated: No Planned From To Survey ft ft 34.30 1200.00 Planned: MPE-32 wp10 V79 1200.00 8906.81 Planned: MPE-32 wp10 V79 Casing Points MD ft 2748.83 6227.00 8906.00 . Sperry-SuD Anticollision Report . Date: 3/1612005 Time: 13:17:30 Well: Plan MPE-32. True North 34.3 + 23.557.8 CO-Ordinate(NE) RefeÌ'eDce: Vertical (TVD) Reference: . Reference: Error Model: Scan Method: Error Suñace: Db: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cytinder North Ellipse + Casing Version: 3 Toolcode Tool Name CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station TVD DIameter Hole Size Name ft in In 2657.80 10.750 12.250 103/4" 4357.80 7.625 9.875 7 518" 4382.79 4.500 6.750 4 1/2" Summary ... Site EX KAVEAR32-25 M Pt E Pad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad M Pt E Pad M Pt E Pad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad M Pt E Pad MPtEPad MPtEPad MPtEPad MPtEPad MPtEPad Offset WeUpath Well KAVEAR32-25 Jet MPE-02 MPE-03 MPE-04 MPE-05 MPE-06 MPE-07 MPE-08 MPE-09 MPE-090H MPE-10 MPE-13 MPE-13 MPE-13 MPE-13 MPE-13 MPE-16 MPE-19 MPE-21 MPE-21 MPE-22 MPE-23 MPE-26 MPE-29 MPE-29 MPE-30 MPE-30 MPE-30 MPE-30 MPE-30 MPE-33 Plan MPE-12 Plan MPE-28 Plan MPE-31 Plan MPE-32 >- Reference Offset C.tr-Ctr N~ Allówablê Wellpath MD MD Dlstånce Arèa Deviation ft ft ft ft ft KAVEAR32-25 V8 1048.83 1050.00 86.10 44.58 41.52 Pass: Major Risk Plan Jet V2 Plan: Jet 399.96 400.00 397.15 9.87 387.28 Pass: Major Risk MPE-02 V1 724.48 725.00 41.64 16.44 25.20 Pass: Major Risk MPE-03 V1 522.61 525.00 151.21 12.34 138.86 Pass: Major Risk MPE-04 V3 650.71 650.00 61.28 14.52 46.77 Pass: Major Risk MPE-05 V1 576.87 575.00 136.86 14.70 122.16 Pass: Major Risk MPE-06 V1 753.03 750.00 205.60 19.06 186.53 Pass: Major Risk MPE-07 V1 1275.40 1275.00 257.03 26.60 230.44 Pass: Major Risk MPE-08 V1 1867.22 1875.00 71.95' 49.36 22.59/ Pass: Major Risk MPE-09 V2 596.44 600.00 253.87 11.77 242.09 Pass: Major Risk MPE-090H V1 596.44 600.00 253.85 11.57 242.28 Pass: Major Risk MPE-10 V1 935.16 950.00 158.50 17.07 141.43 Pass: Major Risk MPE-13 V3 546.84 550.00 207.37 10.89 196.48 Pass: Major Risk MPE-13A V3 546.84 550.00 207.37 10.63 196.75 Pass: Major Risk MPE-13APB1 V3 546.84 550.00 207.37 10.63 196.75 Pass: Major Risk MPE-13APB2 V3 546.84 550.00 207.37 10.63 196.75 Pass: Major Risk MPE-13B V8 546.84 550.00 207.37 10.63 196.75 Pass: Major Risk MPE-16 V6 1924.93 1925.00 199.10 34.99 164.11 Pass: Major Risk MPE-19 V2 1418.68 1475.00 250.89 29.35 221.54 Pass: Major Risk MPE-21 V16 526.19 525.00 230.27 9.29 220.98 Pass: Major Risk Plan#1 MPE-21A VO Plan 526.19 525.00 230.27 9.51. 220.76 Pass: Major Risk MPE-22 V1 595.45 600.00 174.60 11.06 163.54 Pass: Major Risk MPE-23 V6 1329.24 1325.00 317.90 21.79 296.11 Pass: Major Risk MPE-26 V23 571.64 575.00 228.47 10.18 218.30 Pass: Major Risk MPE-29 V2 275.00 275.00 189.62 5.57 184.05 Pass: Major Risk MPE-29PB1 V16 275.00 275.00 189.62 5.41 184.20 Pass: Major Risk MPE-3O V8 2624.98 2650.00 77.85 57.57 20.27 Pass: Major Risk MPE-30A V14 2624.98 2650.00 77.85 157.66 20.19 Pass: Major Risk MPE-3OAL 1 V8 2624.98 2650.00 77.85 57.66 20.18 Pass: Major Risk MPE-3OAPB1 V1 2624.98 2650.00 77.85 57.68 20.17 ' Pass: Major Risk MPE30AL 1 PB V1 2624.98 2650.00 77.85 57.69 20.15 Pass: Major Risk MPE-33 V5 349.99 350.00 71.59 6.76 64.84 Pass: Major Risk MPE-12 V1 Plan: MPE-12 1897.36 1875.00 307.68 37.70 269.98 Pass: Major Risk MPE-28 V1 Plan: MPE-28 399.99 400.00 162.69 9.90 152.79 Pass: Major Risk MPE-31 V1 Plan: MPE-31 625.24 625.00 31.51 14.30 17.22 Pass: Major Risk MPE-32 L 1 V1 Plan: MPE 5325.00 5325.00 0.00 0.00 0.00 FAIL: NOERRORS . . Sperry-Sun Anticollision Report Site: EX KAVEAR32-25 Well: KAVEAR32-25 Rule Assigned: Major Risk Wellpath: KAVEAR32-25 V8 Inter-Site Error: 0.00 ft ft 57.80 57.80 57.80 57.80 0.05 0.00 140.81 140.81 20.000 83.21 1.74 81.46 Pass 75.00 75.00 75.00 75.00 0.09 0.11 140.81 140.81 20.000 83.21 2.38 80.83 Pass 100.00 100.00 100.00 100.00 0.15 0.28 140.81 140.81 20.000 83.21 3.30 79.91 Pass 125.00 125.00 125.00 125.00 0.24 0.45 140.81 140.81 20.000 83.21 4.31 78.90 Pass 150.00 150.00 150.00 150.00 0.32 0.61 140.81 140.81 20.000 83.21 5.32 77.89 Pass 175.00 175.00 175.00 175.00 0.41 0.78 140.81 140.81 20.000 83.21 6.33 76.88 Pass 200.00 200.00 200.00 200.00 0.50 0.95 140.81 140.81 20.000 83.21 7.33 75.87 Pass 225.00 225.00 225.00 225.00 0.55 1.11 140.81 140.81 20.000 83.21 8.25 74.96 Pass 250.00 250.00 250.00 250.00 0.61 1.28 140.81 140.81 20.000 83.21 9.16 74.04 Pass 275.00 275.00 275.00 275.00 0.66 1.45 140.81 140.81 20.000 83.21 10.08 73.13 Pass 300.00 300.00 300.00 300.00 0.72 1.61 140.81 140.81 20.000 83.21 10.99 72.21 Pass 325.00 325.00 325.00 325.00 0.77 1.78 140.81 140.81 20.000 83.21 11.88 71.32 Pass 350.00 350.00 350.00 350.00 0.81 1.95 140.81 140.81 20.000 83.21 12.77 70.43 Pass 375.00 375.00 375.00 375.00 0.86 2.11 140.81 140.81 20.000 83.21 13.67 69.54 Pass 400.00 400.00 400.00 400.00 0.91 2.28 140.81 140.81 20.000 83.21 14.56 68.65 Pass 425.09 425.09 425.00 425.00 0.94 2.44 140.85 75.85 20.000 83.19 15.40 67.79 Pass 450.18 450.18 450.00 450.00 0.97 2.61 140.96 75.96 20.000 83.15 16.25 66.90 Pass 475.26 475.26 475.00 475.00 1.00 2.78 141.14 76.14 20.000 83.09 17.10 65.99 Pass 500.35 500.34 500.00 500.00 1.04 2.94 141.40 76.40 20.000 82.99 17.95 65.05 Pass 525.43 525.42 525.00 525.00 1.07 3.13 141.73 76.73 13.375 82.88 18.56 64.32 Pass 550.50 550.48 550.00 550.00 1.11 3.48 142.14 77.14 13.375 82.75 19.86 62.90 Pass 575.57 575.54 575.00 575.00 1.14 3.84 142.63 77.63 13.375 82.62 21.15 61.47 Pass 600.63 600.59 600.00 600.00 1.17 4.20 143.20 78.20 13.375 82.48 22.44 60.04 Pass 625.68 625.63 625.00 625.00 1.21 4.55 143.86 78.86 13.375 82.34 23.72 58.61 Pass 650.73 650.65 650.00 650.00 1.25 4.91 144.60 79.60 13.375 82.20 25.01 57.19 Pass 675.76 675.66 675.00 675.00 1.28 5.27 145.42 80.42 13.375 82.07 26.28 55.79 Pass 700.79 700.65 700.00 700.00 1.32 5.62 146.33 81.33 13.375 81.95 27.55 54.41 Pass 725.80 725.62 725.00 725.00 1.35 5.98 147.32 82.32 13.375 81.86 28.81 53.04 Pass 750.79 750.57 750.00 750.00 1.39 6.34 148.39 83.39 13.375 81.79 30.07 51.72 Pass 775.78 775.51 775.00 775.00 1.43 6.69 149.55 84.55 13.375 81.75 31.32 50.43 Pass 800.74 800.42 BOO.OO 800.00 1.47 7.05 150.79 85.79 13.375 81.75 32.55 49.19 Pass 825.69 825.30 825.00 825.00 1.51 7.40 152.11 87.11 13.375 81.79 33.79 48.01 Pass 850.63 850.16 850.00 850.00 1.55 7.76 153.51 88.51 13.375 81.89 35.01 46.88 Pass 875.54 875.00 875.00 875.00 1.59 8.11 154.98 89.98 13.375 82.05 36.23 45.83 Pass 900.44 899.80 900.00 899.99 1.63 8.46 156.53 91.53 13.375 82.29 37.43 44.86 Pass 925.29 924.55 925.00 924.99 1.67 8.82 158.18 93.18 13.375 82.60 38.64 43.96 Pass 950.10 949.24 950.00 949.99 1.72 9.17 159.98 94.98 13.375 83.02 39.84 43.18 Pass 974.87 973.85 975.00 974.99 1.77 9.51 161.90 96.90 13.375 83.56 41.02 42.54 Pass 999.58 998.40 1000.00 999.99 1.81 9.86 163.94 98.94 13.375 84.24 42.20 42.04 Pass 1024.24 1022.85 1025.00 1024.99 1.87 10.21 166.09 101.09 13.375 85.08 43.39 41.69 Pass 1048.83 1047.23 1050.00 1049.99 1.92 10.55 168.34 103.34 13.375 86.10 44.58 41.52 Pass 1073.37 1071.51 1075.00 1074.98 1.97 11.03 170.67 105.67 13.375 87.32 45.66 41.66 Pass 1097.84 1095.70 1100.00 1099.98 2.03 11.51 173.05 108.05 13.375 88.74 46.71 42.03 Pass 1122.12 1119.66 1125.00 1124.98 2.09 11.99 175.51 110.51 13.375 90.40 47.78 42.62 Pass 1146.28 1143.46 1150.00 1149.98 2.16 12.47 178.06 113.06 13.375 92.34 48.85 43.49 Pass 1170.33 1167.08 1175.00 1174.97 2.23 12.94 180.66 115.66 13.375 94.59 49.93 44.66 Pass 1194.26 1190.53 1200.00 1199.97 2.30 13.41 183.30 118.30 13.375 97.17 51.02 46.15 Pass 1218.05 1213.79 1225.00 1224.97 2.34 13.88 185.95 120.95 13.375 100.11 52.08 48.03 Pass 1241.72 1236.86 1250.00 1249.97 2.38 14.34 188.58 123.58 13.375 103.41 53.15 50.26 Pass 1265,24 1259.72 1275.00 1274.97 2.41 14.79 191.17 126.17 13.375 107.09 54.27 52.83 Pass 1288.62 1282.37 1300.00 1299.96 2.45 15.25 193.71 128.71 13.375 111.16 55.43 55.74 Pass . . Sperry-SuD Anticollision Report Site: Well: Wellpath: EX KAVEAR32-25 KAVEAR32-25 KAVEAR32-25 V8 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 1311.84 1304.80 1325.00 1324.96 2.47 15.71 196.17 131.17 13.375 115.63 56.61 59.02 Pass 1334.91 1327.01 1350.00 1349.96 2.47 16.21 198.55 133.55 13.375 120.50 57.87 62.63 Pass 1357.81 1348.98 1375.00 1374.96 2.47 16.71 200.83 135.83 13.375 125.77 59.19 66.58 Pass 1380.55 1370.72 1400.00 1399.96 2.48 17.20 203.01 138.01 13.375 131.43 60.55 70.89 Pass 1403.20 1392.29 1425.00 1424.95 2.48 17.69 205.08 140.08 13.375 137.48 61.95 75.53 Pass 1426.24 1414.17 1450.00 1449.95 2.49 18.20 207.02 142.02 13.375 143.85 63.45 80.40 Pass 1449.19 1435.93 1475.00 1474.95 2.50 18.71 208.83 143.83 13.375 150.48 64.99 85.50 Pass 1472.04 1457.54 1500.00 1499.95 2.51 19.21 210.51 145.51 13.375 157.37 66.54 90.83 Pass 1494.80 1479.03 1525.00 1524.94 2.51 19.72 212.08 147.08 13.375 164.50 68.12 96.39 Pass 1517.46 1500.38 1550.00 1549.94 2.52 20.22 213.54 148.54 13.375 171.87 69.71 102.16 Pass 1540.29 1521.84 1575.00 1574.94 2.54 20.73 214.90 149.90 13.375 179.44 71.34 108.10 Pass 1563.73 1543.87 1600.00 1599.94 2.55 21.26 216.15 151.15 13.375 187.15 73.07 114.08 Pass 1587.18 1565.90 1625.00 1624.94 2.56 21.79 217.30 152.30 13.375 194.93 74.80 120.13 Pass 1610.62 1587.93 1650.00 1649.93 2.58 22.33 218.37 153.37 13.375 202.79 76.54 126.25 Pass 1634.06 1609.96 1675.00 1674.93 2.60 22.86 219.36 154.36 13.375 210.71 78.29 132.42 Pass 1657.50 1631.99 1700.00 1699.93 2.62 23.39 220.27 155.27 13.375 218.69 80.04 138.65 Pass 1680.95 1654.02 1725.00 1724.93 2.63 23.93 221.12 156.12 13.375 226.73 81.79 144.93 Pass 1704.39 1676.05 1750.00 1749.93 2.65 24.46 221.91 156.91 13.375 234.81 83.55 151.26 Pass 1727.83 1698.08 1775.00 1774.92 2.67 24.99 222.65 157.65 13.375 242.93 85.31 157.62 Pass 1751.28 1720.11 1800.00 1799.92 2.69 25.52 223.34 158.34 13.375 251.09 87.07 164.02 Pass 1774.72 1742.14 1825.00 1824.92 2.72 26.06 223.99 158.99 13.375 259.28 88.83 170.45 Pass 1798.16 1764.17 1850.00 1849.92 2.74 26.59 224.59 159.59 13.375 267.50 90.58 176.92 Pass 1821.61 1786.20 1875.00 1874.91 2.76 27.12 225.17 160.17 13.375 275.76 92.35 183.41 Pass 1845.05 1808.22 1900.00 1899.91 2.79 27.66 225.70 160.70 " 13.375 284.03 94.11 189.92 Pass 1868.49 1830.25 1925.00 1924.91 2.81 28.19 226.21 161.21 13.375 292.33 95.87 196.47 Pass 1891.93 1852.28 1950.00 1949.91 2.84 28.72 226.69 161.69 13.375 300.66 97.63 203.03 Pass 1915.38 1874.31 1975.00 1974.91 2.87 29.27 227.14 162.14 9.625 309.00 99.26 209.74 Pass 1938.82 1896.34 2000.00 1999.90 2.89 29.82 227.57 162.57 9.625 317.36 101.06 216.30 Pass 1962.26 1918.37 2025.00 2024.90 2.92 30.36 227.98 162.98 9.625 325.74 102.86 222.88 Pass 1985.71 1940.40 2050.00 2049.90 2.95 30.91 228.37 163.37 9.625 334.14 104.65 229.48 Pass 2009.68 1962.93 2075.00 2074.90 2.98 31.47 228.75 163.49 9.625 342.53 106.50 236.02 Pass 2033.13 1984.98 2100.00 2099.90 3.01 32.01 229.11 163.85 9.625 350.91 108.30 242.61 Pass 2056.58 2007.03 2125.00 2124.89 3.04 32.56 229.45 164.18 9.625 359.31 110.11 249.20 Pass 2080.04 2029.07 2150.00 2149.89 3.07 33.11 229.77 164.51 9.625 367.72 111.90 255.82 Pass 2103.49 2051.12 2175.00 2174.89 3.10 33.66 230.08 164.82 9.625 376.14 113.70 262.44 Pass 2126.94 2073.17 2200.00 2199.89 3.14 34.21 230.37 165.11 9.625 384.58 115.51 269.07 Pass 2150.40 2095.22 2225.00 2224.88 3.17 34.76 230.66 165.39 9.625 393.02 117.31 275.71 Pass 2173.85 2117.27 2250.00 2249.88 3.21 35.31 230.93 165.66 9.625 401.47 119.11 282.36 Pass 2197.30 2139.32 2275.00 2274.88 3.24 35.86 231.18 165.92 9.625 409.93 120.91 289.02 Pass 2220.76 2161.36 2300.00 2299.88 3.28 36.40 231.43 166.17 9.625 418.40 122.71 295.69 Pass 2244.21 2183.41 2325.00 2324.88 3.31 36.95 231.67 166.41 9.625 426.87 124.51 302.36 Pass 2267.66 2205.46 2350.00 2349.87 3.35 37.50 231.90 166.64 9.625 435.36 126.31 309.05 Pass 2291.12 2227.51 2375.00 2374.87 3.38 38.05 232.12 166.86 9.625 443.84 128.11 315.74 Pass 2314.57 2249.56 2400.00 2399.87 3.42 38.60 232.34 167.07 9.625 452.34 129.91 322.43 Pass 2338.02 2271.60 2425.00 2424.87 3.46 39.15 232.54 167.28 9.625 460.84 131.71 329.13 Pass 2361.48 2293.65 2450.00 2449.87 3.50 39.70 232.74 167.47 9.625 469.35 133.51 335.84 Pass 2384.93 2315.70 2475.00 2474.86 3.54 40.25 232.93 167.66 9.625 477.86 135.31 342.55 Pass 2408.38 2337.75 2500.00 2499.86 3.57 40.80 233.11 167.85 9.625 486.38 137.11 349.27 Pass 2431.84 2359.80 2525.00 2524.86 3.61 41.34 233.29 168.03 9.625 494.90 138.91 355.99 Pass 2455.29 2381.84 2550.00 2549.86 3.65 41.89 233.46 168.20 9.625 503.43 140.71 362.72 Pass 2478.74 2403.89 2575.00 2574.85 3.69 42.44 233.62 168.36 9.625 511.96 142.51 369.45 Pass . . Sperry-SuD Anticollision Report Site: WeD: WeDpath: EX KAVEAR32-25 KAVEAR32-25 KAVEAR32-25 V8 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 2502.20 2425.94 2600.00 2599.85 3.73 42.99 233.78 168.52 9.625 520.50 144.31 376.18 Pass 2525.65 2447.99 2625.00 2624.85 3.77 43.54 233.94 168.68 9.625 529.04 146.12 382.92 Pass 2549.10 2470.04 2650.00 2649.85 3.81 44.09 234.09 168.83 9.625 537.58 147.92 389.66 Pass 2572.56 2492.09 2675.00 2674.85 3.86 44.64 234.23 168.97 9.625 546.13 149.72 396.41 Pass 2596.01 2514.13 2700.00 2699.84 3.90 45.19 234.38 169.11 9.625 554.68 151.52 403.16 Pass 2619.47 2536.18 2725.00 2724.84 3.94 45.73 234.51 169.25 9.625 563.23 153.32 409.91 Pass 2642.92 2558.23 2750.00 2749.84 3.98 46.28 234.64 169.38 9.625 571.79 155.12 416.66 Pass 2666.37 2580.28 2775.00 2774.84 4.02 46.83 234.77 169.51 9.625 580.35 156.93 423.42 Pass 2689.83 2602.33 2800.00 2799.84 4.07 47.38 234.90 169.64 9.625 588.91 158.73 430.18 Pass 2713.28 2624.37 2825.00 2824.83 4.11 47.93 235.02 169.76 9.625 597.48 160.53 436.95 Pass 2736.73 2646.42 2850.00 2849.83 4.15 48.48 235.14 169.87 9.625 606.04 162.33 443.71 Pass 2760.19 2668.47 2875.00 2874.83 4.20 49.03 235.25 169.99 9.625 614.61 164.13 450.48 Pass 2783.64 2690.52 2900.00 2899.83 4.24 49.58 235.36 170.10 9.625 623.19 165.94 457.25 Pass 2807.09 2712.57 2925.00 2924.82 4.28 50.13 235.47 170.21 9.625 631.76 167.64 464.12 Pass 2830.55 2734.62 2950.00 2949.82 4.33 50.67 235.58 170.31 9.625 640.34 169.44 470.90 Pass 2854.00 2756.66 2975.00 2974.82 4.37 51.22 235.68 170.42 9.625 648.92 171.24 477.67 Pass 2877.45 2778.71 3000.00 2999.82 4.42 51.77 235.78 170.52 9.625 657.50 173.05 484.45 Pass 2900.91 2800.76 3025.00 3024.82 4.46 52.32 235.88 170.61 9.625 666.08 174.85 491.23 Pass 2924.36 2822.81 3050.00 3049.81 4.50 52.87 235.97 170.71 9.625 674.67 176.65 498.01 Pass 2947.81 2844.86 3075.00 3074.81 4.55 53.42 236.06 170.80 9.625 683.25 178.45 504.80 Pass 2971.27 2866.90 3100.00 3099.81 4.60 53.96 236.15 170.89 9.625 691.84 180.25 511.60 Pass 2994.72 2888.95 3125.00 3124.81 4.64 54.51 236.24 170.98 9.625 700.43 182.04 518.40 Pass 3018.17 2911.00 3150.00 3149.81 4.69 55.06 236.33 171.07 9.625 709.03 183.83 525.19 Pass 3041.63 2933.05 3175.00 3174.80 4.73 55.60 236.41 171.15 9.625 717.62 185.63 531.99 Pass 3065.08 2955.10 3200.00 3199.80 4.78 56.15 236.49 171.23 9.625 726.21 187.42 538.80 Pass 3088.53 2977.14 3225.00 3224.80 4.82 56.70 236.57 171.31 9.625 734.81 189.21 545.60 Pass 3111.99 2999.19 3250.00 3249.80 4.87 57.24 236.65 171.39 9.625 743.41 191.01 552.40 Pass 3135.44 3021.24 3275.00 3274.79 4.92 57.79 236.73 171.47 9.625 752.01 192.80 559.21 Pass 3158.89 3043.29 3300.00 3299.79 4.96 58.34 236.80 171.54 9.625 760.61 194.59 566.01 Pass 3182.35 3065.34 3325.00 3324.79 5.01 58.88 236.88 171.61 9.625 769.21 196.39 572.82 Pass 3205.80 3087.39 3350.00 3349.79 5.06 59.43 236.95 171.68 9.625 777.81 198.18 579.63 Pass 3229.25 3109.43 3375.00 3374.79 5.10 59.98 237.02 171.75 9.625 786.42 199.98 586.44 Pass 3252.71 3131.48 3400.00 3399.78 5.15 60.52 237.09 171.82 9.625 795.02 201.77 593.25 Pass 3276.16 3153.53 3425.00 3424.78 5.20 61.07 237.15 171.89 9.625 803.63 203.57 600.06 Pass 3299.61 3175.58 3450.00 3449.78 5.25 61.62 237.22 171.95 9.625 812.24 205.36 606.88 Pass 3323.07 3197.63 3475.00 3474.78 5.29 62.16 237.28 172.02 9.625 820.85 207.07 613.78 Pass 3346.52 3219.67 3500.00 3499.78 5.34 62.71 237.34 172.08 9.625 829.46 208.63 620.83 Pass 3369.97 3241.72 3525.00 3524.77 5.39 63.26 237.41 172.14 9.625 838.07 210.19 627.88 Pass 3393.43 3263.77 3550.00 3549.77 5.44 63.80 237.47 172.20 9.625 846.68 211.75 634.93 Pass 3416.88 3285.82 3575.00 3574.77 5.48 64.35 237.52 172.26 9.625 855.29 213.31 641.98 Pass 3440.33 3307,87 3600.00 3599.77 5.53 64.90 237.58 172.32 9.625 863.90 214.87 649.03 Pass 3463.79 3329.92 3625.00 3624.76 5.58 65.44 237.64 172.38 9.625 872.52 216.43 656.08 Pass 3487.24 3351.96 3650.00 3649.76 5.63 65.99 237.69 172.43 9.625 881.13 218.00 663.14 Pass 3500.00 3363.95 3675.00 3674.76 5.65 66.41 237.80 171.82 9.625 889.83 219.26 670.57 Pass 3521.96 3384.52 3700.00 3699.76 5.69 66.62 237.98 170.31 9.625 898.66 220.15 678.51 Pass 3538.62 3400.07 3725.00 3724.76 5.73 66.90 238.14 169.27 9.625 907.68 221.18 686.50 Pass 3555.18 3415.46 3750.00 3749.75 5.76 67.17 238.32 168.30 9.625 916.87 222.19 694.68 Pass 3571.61 3430.68 3775.00 3774.75 5.79 67.43 238.50 167.39 9.625 926.23 223.20 703.04 Pass 3587.93 3445.74 3800.00 3799.75 5.82 67.68 238.70 166.55 9.625 935.77 224.20 711.57 Pass 3600.00 3456.85 3825.00 3824.75 5.84 67.99 238.88 166.00 9.625 945.48 225.33 720.16 Pass 3620.20 3475.35 3850.00 3849.75 5.88 68.15 239.12 165.05 9.625 955.34 226.18 729.16 Pass 8 <::> -6 "" <::> {Ò 1 49 00 W MPU E...32 Proposed 1..0il Schrader uNC/NDu 2050650 4/25/2005 I o . . SONDRA. D STEWMAN BPEXPLORATION AK INC POBOX 196612 MB7-5 . ANCHORAGE, AK 99519-6612 "Mastercard Check" DATE tr4,-t q - öC¡ 89-6/1252 127 I $ l(SC).,CX') "~ t>OLLAR$ I:. 2S 2000bOI:Qq ......Ib 2 27"1. Sb"'U· 0..27 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /J1¡?a E-32- PTD# :2DS:- -06':;- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well _, Permit No, API No. Production should continue to be reported as a function of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SP ACING EXCEPTION DRY DITCH SAMPLE Rev: 04/01105 C\j ody\trans mittal_ checklist The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce/iniect is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool MILNE POINT. SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB E-32 PTD#: 2050650 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV I PEND GeoArea 890 1 Permittee attached _ Yes _ _ _ _ _ _ _ _ 2 _Lease number appropriate_ _ _ _ _ _ _ _ _ Yes _ Surtace loca_tiol'! in AP!-025518;top prod_uçtjve intel'\laJ andTD_ io ADL 028231. 3 _U_nique weltn_ame_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , - - - - - - - _ - - - - - - , 4 WelUQCÇlted in_a_d_efil'!e~Lpool _ _ _ _ _ _ _ Yes _ _ _ _ MiJnepoint Sc;hra_der_Bluff Oil F'Qol (5251<40), go_vemed by_CO 4'n _ _ _ _ 5 WelUQcç¡ted prpper _distance_ from driJling ul'!ilboUl'!d_ary _ Yes _ _ _ _ _ _ _ CO ~ 7I specifies_gpveJl'!me_ntaJ Otr-Qtr-Qtr seçtjon; proposed_ wellcooforms _tQ this Jequirement. _ 6 WellJQcç¡ted prpperdistance from otbeJ welJs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ CO ~7I specifiesgpveJomentaJ Otr-Qtr:Qtr seçtio_n_ 7 _S_utficiel'!tacreage_ayailable in_drilliog unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ 8 Ifdeviated, js weJlbQre platiocJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ 9 _O-perator ol'!ly: affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-per_ator bas_appropriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit c_an be issued witbQut consel'\latiol'! order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Permit call be issued witbQut ad_mil'!istratillea-pprpval _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - SFD 4/25/2005 13 Can permit be approved before 15-day wait Yes 14 WeJUQcated withil'! area and_strata authorized bY_'ojectioo Order it {puUOil in_cpmmel1tsJ-(for_ NA _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - 15 AJI welJs-'l'iithi¡Ul4_l'IJile_area_of review ideotified (Fpr servjeewell ol'!lY:L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - _ - - - - _ 16 Pre-produced il1jector; _duratio_n_of pre--proJ:!uctioo less_ than 3 montbs_ (for_service well QnJy) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 17 _ACMPJ:il'!dingpfConsistel1c;yhasbeenJssued_forJbisprolecl _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 18 _C_ol1duçtor stril'!g_prQvided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19Surfacecasil'!g_pJotectsalLknownUSDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _Allaquifersexempted.ADCFRH7J02(b)(3). _ _ _ _ _ _ _ __ 20 _CMT vPI adequateJo circ_utate_o_n _cOl'!d_uctor 8. su_rfcsg _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ 21 _CMT vol adequateJo tie-inJQng _stril1g to_surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ All hydrocarbQn_z~)lJes_pJa_noedJo be co_vered._ 22 _CMTwilJ c;oyer_aJl koownproduc;tiye bQrizon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ Sc;ree_ned lin_er proposed. _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asing designs ad_eQuate fpr C,T" B_&permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - 24 _MequateJanJ<age_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig is_e_quippedwith steelpits. No_ resewe_pjt-planoe_d, AJI waste to_Class Jlwell(s), _ 25 IfaJe-J:!rilt has a 10-403 fQr abandonment beeo apPJQved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 _Mequatewellbore separatio_n _pro-PQseJ:!_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _YeL _ _ _ _ _ _ I?r~))~imity. I:!nalysis perto(1l)e_d, Jrayeling çy:lioder pIOlPJQvided., Gyros possible._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Ifdjverter Jequired, dQes it meet reguJaJiol'!s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - 28 _DJilIiog fluid_pJogram schematic_&. eq_uiplistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Maxil'lJum expected fp(1l)atiOI1 pres_sure_8,3_EMW._ PlaOl'!eJ:!MW up t09A in inteJmedJat hole,_9,0_ io 5B._ 29 _BOPEs,dp Jhey meet regulatioo _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 _BOPE_pre_ss ratiog ap-propril:!te;Jestto_(pu_t psig in_commel'!ts) _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASF' Cl:!lc;uJate_d_at 1913psi, Plaooe_d_B_QPJest30QO_p-st 31Chokeml:!nifold cQmplies w/APIRF'-53 (May 84) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - 32 WQrk will occ_ur withoutoperatjonshutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - _ - - - - - - - 33 Is presence Qf H2S gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ 1:128 oot reporte_d In SB wells._ RigJs equipped_ with seosors and alarms, _ _ _ _ _ _ _ _ _ 34 Mecba_nicaLcoodJt[on pf wells withil'! AOR verified (For_s_ervice welJ only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Administration Engineering Appr Date TEM 4/26/2005 Ill·M Geology Appr SFD Date 4/26/2005 Geologic Commissioner: f) Ts Unit Program DEV On/Off Shore On D D 11328 Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . 35 Permilcaobeissuedwlo_hydrpgen_sulfidemeI:!SJ,Jre~L _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _WalteJQJ,Jay" BP,4J26/Q5_-MH2Sm_easuredjoSBalMF'U E-Pad. SF P_ 36 _D_ata_preseoted on pote_ntil:!l oveJpres_sure _ZOl'!es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Expected resel'\lojr -preSSUJe is 8,35 ppg EMW; wiJI be drilled with 9.0 ppg_l'IJud, _ 37 _Seismicanalysjs_ Qf sballow 9aszpoes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ l:Iydrateshave be_en eocoUl'!tered in E_-F'ad_weJls between 22QO_8. 25_00TVD, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38 Seabed _CQl'!ditioo SUl'\ley _(if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ Noted in PrilJiog Ha_zards section. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ CQnta_ct l'!amelphoneJorweekly progress_reports [exploratory pnly] _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - Date: Engineering Commissioner: ~ Date ~~r Date 1--)<:] Is . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility e l 1\'-_ 0Û) 01.::\ $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 24 10:01:57 2005 .tt 1>:.t\J. Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... .... ...... ..UNKNOWN Continuation Number.... ..01 Previous Reel Name. . . . . . .UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Tape Header Service name..... ...... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........ ...... ..UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-32 PB1 500292326170 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 24-JUN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003696012 R. FRENCH E. VAUGHN MWD RUN 2 MW0003696012 R. FRENCH E. VAUGHN MWD RUN 3 MW0003696012 C.A. DEMOSKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003696012 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 13N 10E 3984 2032 56.04 22.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SI. (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 122.0 2746.0 6299.0 e # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 4 ALSO INCLUDED PRESSURE - WHILE - DRIIJLING (PWD) , AND AT-BIT INCLINATION (ABI). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CONVERSATION BETWEEN DENNIS m~BAN (BP GEOSCIENTIST) AND BUSTER BRYANT (SDS) ON 4/13/05. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-4 REPRESENT WELL MPE-32 PB1 WITH API#: 50-029-23261-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8045'MD/4340'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMI' = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.......05/06/24 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM 1 and clipped curves; all bit runs merged. .5000 START DEPTH 77.0 100.5 100.5 100.5 STOP DEPTH 7988.5 7995.5 7995.5 7995.5 RPS RPX ROP $ 100.5- 100.5 115.5 7995.5 7995.5 8045.0 _ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 77.0 2756.0 2918.0 6310.0 MERGE BASE 2756.0 2918.0 6310.0 8045.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... .... ......... ..0 Data Specification Block Type... ..0 Logging Direction....... ........ ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................ .... .60 .1IN Max frames per record....... ......Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77 8045 4061 15937 77 8045 ROP MWD FT/H 1. 06 2269.25 196.298 15860 115.5 8045 GR MWD API 9.95 124.41 66.0341 15799 77 7988.5 RPX MWD OHMM 0.38 1493.2 13.638 15766 100.5 7995.5 RPS MWD OHMM 0.06 1494.05 18.0369 15766 100.5 7995.5 RPM MWD OHMM 0.24 2000 30.6154 15766 100.5 7995.5 RPD MWD OHMM 0.2 2000 41.5909 15766 100.5 7995.5 FET MWD HOUR 0.09 52 1. 2459 15766 100.5 7995.5 First Reading For Entire File......... .77 Last Reading For Entire File..... ..... .8045 File Trailer Service name... ......... .STSLIB.001 Service Sub Level Name. . . Version Number........ ...1.0.0 Date of Generation.. .....05/06/24 Maximum Physical Record..65535 File Type... ............ ~ Next File Name.......... .STSLIB.002 Physical EOF File Header Service name.. .......... .STSLIB.002 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation..... ..05/06/24 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 77.0 100.5 100.5 100.5 100.5 100.5 115.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 2714.0 2706.5 2706.5 2706.5 2706.5 2706.5 2756.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 08-MAY-05 Insite 66.37 Memory 2756.0 122.0 2756.0 .4 21.4 TOOL NUMBER 175785 63122 13.500 .0 SPUD MUD 9.80 96.0 8.0 700 8.0 2.400 62.0 MUD MUD MUD AT MAX CIRCULA.G FILTRATE AT MT: CAKE AT MT: TERMPERATURE: 2.010 3.000 4.000 e 75.2 62.0 62.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction..... ........ ....Down Optical log depth units... ........Feet Data Reference Point... ......... ..Undefined Frame Spacing.. .................. .60 .1IN Max frames per record.......... ...Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77 2756 1416.5 5359 77 2756 ROP MWD010 FT/H 9.53 2269.25 208.735 5282 115.5 2756 GR MWD010 API 21. 73 117.58 62.7237 5275 77 2714 RPX MWD010 OHMM 0.55 108.28 19.7501 5213 100.5 2706.5 RPS MWD010 OHMM 0.1 455.19 31.9425 5213 100.5 2706.5 RPM MWD010 OHMM 0.7 2000 55.0487 5213 100.5 2706.5 RPD MWD010 OHMM 0.33 2000 59.7615 5213 100.5 2706.5 FET MWD010 HOUR 0.14 4.66 0.536841 5213 100.5 2706.5 First Reading For Entire File......... .77 Last Reading For Entire File.... ...... .2756 File Trailer Service name.... ....... ..STSLIB.002 Service Sub Level Name. . . Version Number....... ... .1.0.0 Date of Generation..... ..05/06/24 Maximum Physical Record. .65535 File Type............... .LO Next File Name... ...... ..STSLIB.003 Physical EOF e File Header Service name... ......... .STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type. ... ........... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPD RPX RPM GR ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 2707.0 2707.0 2707.0 2707.0 2707.0 2714.5 2756.5 STOP DEPTH 2874.0 2874.0 2874.0 2874.0 2874.0 2882.0 2918.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTRO MAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 10-MAY-05 Insite 66.37 Memory 2918.0 2756.0 2918.0 20.7 20.8 TOOL NUMBER 132477 66259 9.875 2746.0 LSND 9.00 53.0 8.5 550 7.8 1.800 1. 580 3.000 2.400 62.0 71. 6 63.0 54.0 HOLE CORRECTION (IN): 4IÞ e # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. .............. ..0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing...... ....... ........60 .1IN Max frames per record.. ...........Undefined Absent value... .......... ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2707 2918 2812.5 423 2707 2918 ROP MWD020 FT/H 32.31 910.55 401.291 324 2756.5 2918 GR MWD020 API 27.55 107.13 62.2747 336 2714.5 2882 RPX MWD020 OHMM 0.38 16.75 10.0242 335 2707 2874 RPS MWD020 OHMM 0.06 26.25 10.8713 335 2707 2874 RPM MWD020 OHMM 7.17 2000 54.5232 335 2707 2874 RPD MWD020 OHMM 0.2 2000 312.828 335 2707 2874 FET MWD020 HOUR 0.09 52 15.607 335 2707 2874 First Reading For Entire File.... ..... .2707 Last Reading For Entire File.......... .2918 File Trailer Service name....... ......STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type.......... ......LO Next File Name. ........ ..STSLIB.004 Physical EOF File Header Service name..; ........ ..STSLIB.004 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name...... ~SLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ 4 e header data for each bit run in separate files. 3 .5000 START DEPTH 2874.5 2874.5 2874.5 2874.5 2874.5 2882.5 2918.5 STOP DEPTH 6266.5 6266.5 6266.5 6266.5 6266.5 6274.0 6310.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY·. (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 13 -MAY-05 Insite 66.37 Memory 6310.0 2918.0 6310.0 19.9 105.6 TOOL NUMBER 132477 66259 9.875 2746.0 LSND 9.00 60.0 8.5 500 8.4 3.200 2.030 2.800 3.500 75.0 122.0 75.0 75.0 # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type. ....0 Logging Direction............ .....Down Optical log depth units...... .....Feet Data Reference.Point...... ........Undefined Frame Spacing...... ...............60 .1IN Max frames per record.. ......... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 e e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2874.5 6310 4592.25 6872 2874.5 6310 ROP MWD030 FT/H 1. 06 91 7.77 195.475 6784 2918.5 6310 GR MWD030 API 9.95 124.41 67.4467 6784 2882.5 6274 RPX MWD030 OHMM 1.3 73.64 9.30897 6785 2874.5 6266.5 RPS MWD030 OHMM 1. 32 80.8 9.60269 6785 2874.5 6266.5 RPM MWD030 OHMM 1.3 1548.67 10.3924 6785 2874.5 6266.5 RPD MWD030 OHMM 1.4 1558.79 10.6862 6785 2874.5 6266.5 FET MWD030 HOUR 0.11 8.67 0.736976 6785 2874.5 6266.5 First Reading For Entire File...... ....2874.5 Last Reading For Entire File........ ...6310 File Trailer Service name... ........ ..STSLIB.004 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation... ....05/06/24 Maximum Physical Record..65535 File Type... ... ........ ..LO Next File Name. ......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number,.. ...... ..1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type... .... ....... ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ e 4 .5000 START DEPTH 6267.0 6267.0 6267.0 6267.0 6267.0 6274.5 6310.5 STOP DEPTH 7995.5 7995.5 7995.5 7995.5 7995.5 7988.5 8045.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. ..... ..........Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined e 16-MAY-05 Insite 66.37 Memory 8045.0 6310.0 8045.0 85.1 99.2 TOOL NUMBER 156436 90518 6.750 6299.0 VERSAPRO 9.10 116.0 .0 43500 .0 .000 .000 .000 .000 .0 .0 .0 .0 Frame Spacing........ ..... ......60 .1IN Max frames per record.... .........Undefined Absent value. . ; . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR Size 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 Name DEPT ROP GR RPX RPS RPM RPD FET MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 Rep 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6267 8045 7156 3557 6267 8045 ROP MWD040 FT/H 6.83 468.16 159.835 3470 6310.5 8045 GR MWD040 API 33.23 103.64 68.7197 3404 6274.5 7988.5 RPX MWD040 OHMM 3.9 1493.2 13.2652 3433 6267 7995.5 RPS MWD040 OHMM 3.94 1494.05 14.2899 3433 6267 7995.5 RPM MWD040 OHMM 0.24 2000 31.1495 3433 6267 7995.5 RPD MWD040 OHMM 0.35 2000 48.6112 3433 6267 7995.5 FET MWD040 HOUR 0.2 49.66 1. 92706 3433 6267 7995.5 First Reading For Entire File.. ....... .6267 Last Reading For Entire File.......... .8045 File Trailer Service name...... ..... ..STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/06/24 Maximum Physical Record..65535 File Type......... .......LO Next File Name... ........STSLIB.006 Physical EOF Tape Trailer Service name......... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ... ......... .UNKNOWN Continuation Number..... .01 Next Tape Name....... ....UNKNOWN Comments......... ...... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.......... ......UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Physical EOF e e Physical EOF End Of LIS File Sperry-Sun Dr~ing Services LIS Scan Utility e d 05"- O(¡; i- Jt I J ).1 J- / $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 24 08:12:32 2005 Reel Header Service name......... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name....... ....... ..UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments.... ........... ..STS LIS writing Library. Scientific Technical Services Tape Header Service name.. .......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ....UNKNOWN Continuation Number.... ..01 Previous Tape Name. . . . . . .UNKNOWN Comments.. .............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-32 500292326100 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 24-JUN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003696012 R. FRENCH E. VAUGHN MWD RUN 2 MW0003696012 R. FRENCH E. VAUGHN MWD RUN 3 MW0003696012 C.A. DEMOSKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003696012 C.A. DEMOSKI E. VAUGHN MWD RUN 5 MW0003696012 C. ZAWADZKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 13N 10E 3984 2032 MSL 0) 56.04 22.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION BIT S. 13.500 9.875 6.750 e (IN) SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 122.0 2746.0 6299.0 STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING MPE-32 PB1 AT 6561'MD/ 4366'TVD. 4. MWD RUNS 1-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 4 & 5 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CONVERSATION BETWEEN DENNIS URBAN (BP GEOSCIENTIST) AND BUSTER BRYANT (SDS) ON 4/13/05. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL MPE-32 WITH API#: 50-029-23261-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8894'MD/4360'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name.... ....... ..STSLIB.001 Service Sub Level Name. . . Version Number...... .....1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type.......... ......LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET 1 and clipped curves; all bit runs merged. .5000 START DEPTH 77.0 100.5 STOP DEPTH 8836.5 8844.0 RPD RPM RPS RPX ROP $ 100.5- 100.5 100.5 100.5 115.5 e 8844.0 8844.0 8844.0 8844.0 8893.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 5 MERGE TOP 77.0 2756.0 2918.0 6310.0 6561.5 MERGE BASE 2756.0 2918.0 6310.0 6561. 0 8893.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ............. ..0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ... ...Feet Data Reference Point............ ..Undefined Frame Spacing... ....... ......... ..60 .1IN Max frames per record............ .Undefined Absent value.......... ...... ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77 8893.5 4485.25 17634 77 8893.5 ROP MWD FT/H 0.77 2269.25 188.742 17557 115.5 8893.5 GR MWD API 9.95 124.41 63.1378 17520 77 8836.5 RPX MWD OHMM 0.38 1880.47 16.2216 17488 100.5 8844 RPS MWD OHMM 0.06 2000 20.9551 17488 100.5 8844 RPM MWD OHMM 0.24 2000 37.297 17488 100.5 8844 RPD MWD OHMM 0.2 2000 45.7262 17488 100.5 8844 FET MWD HOUR 0.09 52 1.19315 17488 100.5 8844 First Reading For Entire File.... ..... .77 Last Reading For Entire File....... ....8893.5 File Trailer Service name.... ....... ..STSLIB.001 Service Sub Level Name. . . version Number:... ..... .~O.O Date of Generation... ....05/06/24 Maximum Physical Record..65535 File Type.. ... .......... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation. ......05/06/24 Maximum Physical Record..65535 File Type... .... ........ .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 77.0 100.5 100.5 100.5 100.5 100.5 115.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 2714.0 2706.5 2706.5 2706.5 2706.5 2706.5 2756.0 08-MAY-05 Insite 66.37 Memory 2756.0 122.0 2756.0 .4 21.4 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 175785 63122 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 13 .500 .0 SPUD MUD 9.80 96 .0 8.0 700 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: e e 8.0 2.400 62.0 2.010 75.2 3.000 62.0 4.000 62.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction.. ......... ......Down Optical log depth units......... ..Feet Data Reference Point... ......... ..Undefined Frame Spacing.. .................. .60 .1IN Max frames per record.......... ...Undefined Absent value........ ........ ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77 2756 1416.5 5359 77 2756 ROP MWD010 FT/H 9.53 2269.25 208.735 5282 115.5 2756 GR MWD010 API 21. 73 117.58 62.7237 5275 77 2714 RPX MWD010 OHMM 0.55 108.28 19.7501 5213 100.5 2706.5 RPS MWD010 OHMM 0.1 455.19 31.9425 5213 100.5 2706.5 RPM MWD010 OHMM 0.7 2000 55.0487 5213 100.5 2706.5 RPD MWD010 OHMM 0.33 2000 59.7615 5213 100.5 2706.5 FET MWD010 HOUR 0.14 4.66 0.536841 5213 100.5 2706.5 First Reading For Entire File... ...... .77 Last Reading For Entire File. ........ ..2756 File Trailer Service name....... ..... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .05/06/24 Maximum Physical Record..65535 File Type.. ............. .LO Next File Name.......... .STSLIB.003 e Physical EOF File Header Service name.... ........ .STSLIB.003 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 2707.0 2707.0 2707.0 2707.0 2707.0 2714.5 2756.5 STOP DEPTH 2874.0 2874.0 2874.0 2874.0 2874.0 2882.0 2918.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL. CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # 10-MAY-05 Insite 66.37 Memory 2918.0 2756.0 2918.0 20.7 20.8 TOOL NUMBER 132477 66259 9.875 2746.0 LSND 9.00 53.0 8.5 550 7.8 1. 800 1.580 3.000 2.400 62.0 71.6 63.0 54.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION e e (IN) : # TOOL STANDOFF (IN): EWR FREQUENCY {HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value... .................. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2707 2918 2812.5 423 2707 2918 ROP MWD020 FT/H 32.31 910.55 401. 291 324 2756.5 2918 GR MWD020 API 27.55 107.13 62.2747 336 2714.5 2882 RPX MWD020 OHMM 0.38 16.75 10.0242 335 2707 2874 RPS MWD020 OHMM 0.06 26.25 10.8713 335 2707 2874 RPM MWD020 OHMM 7.17 2000 54.5232 335 2707 2874 RPD MWD020 OHMM 0.2 2000 312.828 335 2707 2874 FET MWD020 HOUR 0.09 52 15.607 335 2707 2874 First Reading For Entire File......... .2707 Last Reading For Entire File....... ....2918 File Trailer Service name.... ....... ..STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record..65535 File Type..... ,..... .....LO Next File Name..... ......STSLIB.004 Physical EOF File Header Service name......... ....STSLIB.004 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation..... .~/06/24 Maximum Physical Record..65535 File Type........ ...... ..LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 e header data for each bit run in separate files. 3 .5000 START DEPTH 2874.5 2874.5 2874.5 2874.5 2874.5 2882.5 2918.5 STOP DEPTH 6266.5 6266.5 6266.5 6266.5 6266.5 6274.0 6310.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 13-MAY-05 Insite 66.37 Memory 6310.0 2918.0 6310.0 19.9 105.6 TOOL NUMBER 132477 66259 9.875 2746.0 LSND 9.00 60.0 8.5 500 8.4 3.200 2.030 2.800 3.500 75.0 122.0 75.0 75.0 # e e REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type. ....0 Logging Direction... ......... .....Down Optical log depth units........ ...Feet Data Reference Point... .......... .Undefined Frame Spacing........... ......... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2874.5 6310 4592.25 6872 2874.5 6310 ROP MWD030 FT/H 1. 06 917.77 195.475 6784 2918.5 6310 GR MWD030 API 9.95 124.41 67.4467 6784 2882.5 6274 RPX MWD030 OHMM 1.3 73.64 9.30897 6785 2874.5 6266.5 RPS MWD030 OHMM 1. 32 80.8 9.60269 6785 2874.5 6266.5 RPM MWD030 OHMM 1.3 1548.67 10.3924 6785 2874.5 6266.5 RPD MWD030 OHMM 1.4 1558.79 10.6862 6785 2874.5 6266.5 FET MWD030 HOUR 0.11 8.67 0.736976 6785 2874.5 6266.5 First Reading For Entire File......... .2874.5 Last Reading For Entire File.......... .6310 File Trailer Service name....... .... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....05/06/24 Maximum Physical Record..65535 File Type.. ............. .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type....... ....... ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPD FET RPX GR ROP $ e 5 e header data for each bit run in separate files. 4 .5000 START DEPTH 6267.0 6267.0 6267.0 6267.0 6267.0 6274.5 6310.5 STOP DEPTH 6561.0 6561.0 6561. 0 6561. 0 6561. 0 6561.0 6561. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..... ........ ..0 Data Specification Block Type.....O 16-MAY-05 Insite 66.37 Memory 6561. 0 6310.0 6561. 0 85.1 99.2 TOOL NUMBER 156436 90518 6.750 6299.0 VERSAPRO 9.10 116.0 .0 43500 .0 .000 .000 .000 .000 .0 115.0 .0 .0 L ' D" e ogglng lrectlon.... ....... ......Down Optical log depth units... ........Feet Data Reference Point............. .Undefined Frame Spacing... ....... .......... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6267 6561 6414 589 6267 6561 ROP MWD040 FT/H 16.04 416.62 220.316 502 6310.5 6561 GR MWD040 API 33.23 101.71 65.781 574 6274.5 6561 RPX MWD040 OHMM 4.27 1493.2 16.7763 589 6267 6561 RPS MWD040 OHMM 4.33 1494.05 18.1838 589 6267 6561 RPM MWD040 OHMM 0.24 2000 49.702 589 6267 6561 RPD MWD040 OHMM 0.35 2000 132.756 589 6267 6561 FET MWD040 HOUR 0.2 49.66 8.02579 589 6267 6561 First Reading For Entire File......... .6267 Last Reading For Entire File.......... .6561 File Trailer Service name.... ....... ..STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation..... ..05/06/24 Maximum Physical Record..65535 File Type......... ..... ..LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name.. ò.... ......STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.. .....05/06/24 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name... ... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 6 header data for each bit run in separate files. 5 .5000 VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ START .TH 6561. 5 6561. 5 6561. 5 6561.5 6561.5 6561. 5 6561. 5 STOP DEPTH 8844.0 8844.0 8844.0 8844.0 8836.5 8893.5 8844.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ............ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ......Feet Data Reference Point... ......... ..Undefined Frame Spacing.. .................. .60 .1IN Max frames per record........ .....Undefined Absent value....... .... ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . e 17-MAY-05 Insite 66.37 Memory 8894.0 6561. 0 8894.0 86.1 102.8 TOOL NUMBER 156436 90518 6.750 6299.0 VERSA-PRO 9.20 90.0 .0 49000 .0 .000 .000 .000 .000 .0 115.0 .0 .0 Datum Specification BlOC~ub-tYPe. ..0 e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6561. 5 8893.5 7727.5 4665 6561. 5 8893.5 ROP MWD050 FT/H 0 447.11 138.153 4665 6561. 5 8893.5 GR MWD050 API 29.35 104.63 56.9251 4551 6561. 5 8836.5 RPX MWD050 OHMM 3.75 1880.47 22.8482 4566 6561. 5 8844 RPS MWD050 OHMM 3.88 2000 26.3776 4566 6561. 5 8844 RPM MWD050 OHMM 3.88 2000 54.1456 4566 6561. 5 8844 RPD MWD050 OHMM 4.27 2000 50.9477 4566 6561. 5 8844 FET MWD050 HOUR 0.33 28.01 0.681408 4566 6561.5 8844 First Reading For Entire File......... .6561.5 Last Reading For Entire File.......... .8893.5 File Trailer Service name..... ...... ..STSLIB.006 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .05/06/24 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.007 Physical EOF Tape Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number.. ....01 Next Tape Name......... ..UNKNOWN Comments... .... ......... .STS LIS Writing Library. Scientific Technical Services Reel 'Trailer Service name....... ......LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number.... ..01 Next Reel Name......... ..UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF . e . End Of LIS File